Form 10-Q
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D. C. 20549
FORM 10-Q
(Mark One)
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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 |
For the quarterly period ended September 30, 2010
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 |
For the transition period from to
Commission file number 1-11953
Willbros Group, Inc.
(Exact name of registrant as specified in its charter)
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Delaware
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30-0513080 |
(Jurisdiction of incorporation)
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(I.R.S. Employer Identification Number) |
4400 Post Oak Parkway
Suite 1000
Houston, TX 77027
Telephone No.: 713-403-8000
(Address, including zip code, and telephone number, including
area code, of principal executive offices of registrant)
NOT APPLICABLE
(Former name, former address and former fiscal year, if changed since last report)
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 has submitted electronically and posted on its
corporate Web site, if any, every Interactive Data File required to be submitted and posted
pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter
period that the registrant was required to submit and post such files). Yes o No o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a
non-accelerated filer, or a smaller reporting company. See definitions of large accelerated
filer, accelerated filer and smaller reporting company in Rule 12b-2 of the Exchange Act.
(Check one):
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Large Accelerated Filer o
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Accelerated Filer þ
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Non-Accelerated Filer o
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Smaller reporting company 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
The
number of shares of the registrants Common Stock, $.05 par
value, outstanding as of November 5, 2010 was 47,874,908.
WILLBROS GROUP, INC.
FORM 10-Q
FOR QUARTER ENDED SEPTEMBER 30, 2010
2
WILLBROS GROUP, INC.
CONDENSED CONSOLIDATED BALANCE SHEETS
(In thousands, except share and per share amounts)
(Unaudited)
PART I FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
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September 30, |
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December 31, |
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2010 |
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2009 |
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ASSETS
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Current assets: |
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Cash and cash equivalents |
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$ |
100,887 |
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$ |
198,774 |
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Short-term investments |
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16,559 |
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Accounts receivable, net |
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366,388 |
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162,460 |
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Contract cost and recognized income not yet billed |
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32,986 |
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45,009 |
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Prepaid expenses and other |
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42,924 |
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15,530 |
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Parts and supplies inventories |
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10,348 |
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4,666 |
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Deferred income taxes |
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6,796 |
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2,875 |
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Total current assets |
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560,329 |
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445,873 |
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Property, plant and equipment, net |
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272,506 |
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132,879 |
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Goodwill |
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258,975 |
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85,775 |
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Other intangible assets, net |
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201,736 |
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|
36,772 |
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Deferred income taxes |
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9,179 |
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25,034 |
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Other assets |
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39,428 |
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2,045 |
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Total assets |
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$ |
1,342,153 |
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$ |
728,378 |
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LIABILITIES AND STOCKHOLDERS EQUITY
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Current liabilities: |
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Accounts payable and accrued liabilities |
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$ |
192,573 |
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$ |
81,821 |
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Contract billings in excess of cost and recognized income |
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18,059 |
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11,336 |
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Current portion of capital lease obligations |
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7,248 |
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5,824 |
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Notes payable and current portion of other long-term debt |
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102,634 |
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31,450 |
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Current portion of government obligations |
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6,575 |
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6,575 |
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Accrued income taxes |
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11,516 |
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1,605 |
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Other current liabilities |
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2,671 |
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9,968 |
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Liabilities of discontinued operations |
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791 |
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Total current liabilities |
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342,067 |
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148,579 |
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Long-term debt |
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276,386 |
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56,071 |
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Capital lease obligations |
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8,727 |
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10,692 |
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Contingent earnout |
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10,000 |
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Long-term portion of government obligations |
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6,575 |
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Long-term liabilities for unrecognized tax benefits |
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4,510 |
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5,512 |
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Deferred income taxes |
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89,604 |
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11,356 |
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Other long-term liabilities |
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27,758 |
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1,598 |
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Total liabilities |
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759,052 |
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240,383 |
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Contingencies and commitments (Note 16) |
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Stockholders equity: |
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Preferred stock, par value $.01 per share, 1,000,000 shares authorized, none issued |
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Common stock, par value $.05 per share, 70,000,000 shares authorized and
48,467,080 shares issued at September 30, 2010 (40,106,498 at December 31,
2009) |
|
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2,420 |
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2,005 |
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Capital in excess of par value |
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670,495 |
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|
607,299 |
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Accumulated deficit |
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(94,055 |
) |
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(124,788 |
) |
Treasury stock at cost, 607,534 shares at September 30, 2010
(510,187 at December 31, 2009) |
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(9,939 |
) |
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(9,045 |
) |
Accumulated other comprehensive income |
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13,421 |
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11,725 |
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Total Willbros Group, Inc. stockholders equity |
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582,342 |
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487,196 |
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Noncontrolling interest |
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759 |
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799 |
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Total stockholders equity |
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583,101 |
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487,995 |
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Total liabilities and stockholders equity |
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$ |
1,342,153 |
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$ |
728,378 |
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See accompanying notes to condensed consolidated financial statements.
3
WILLBROS GROUP, INC.
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(In thousands, except share and per share amounts)
(Unaudited)
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Three Months Ended |
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Nine Months Ended |
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September 30, |
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September 30, |
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2010 |
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2009 |
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2010 |
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2009 |
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Contract revenue |
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$ |
408,792 |
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$ |
247,533 |
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$ |
793,917 |
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$ |
1,065,941 |
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Operating expenses: |
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Contract |
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350,135 |
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222,330 |
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687,918 |
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941,129 |
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Amortization of intangibles |
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3,921 |
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|
960 |
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5,826 |
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5,554 |
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General and administrative |
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35,347 |
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17,469 |
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82,593 |
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61,620 |
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Goodwill impairment |
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12,000 |
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12,000 |
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Changes in fair value of contingent earnout liability |
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(45,340 |
) |
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(45,340 |
) |
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Acquisition costs |
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7,947 |
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|
857 |
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9,912 |
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|
942 |
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Other charges |
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85 |
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2,418 |
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|
698 |
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|
8,207 |
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|
|
|
|
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|
364,095 |
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244,034 |
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753,607 |
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1,017,452 |
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Operating income |
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44,697 |
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|
3,499 |
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|
40,310 |
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|
48,489 |
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Other income (expense): |
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|
|
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Interest income |
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|
137 |
|
|
|
469 |
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|
|
656 |
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|
|
1,742 |
|
Interest expense |
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(11,973 |
) |
|
|
(2,446 |
) |
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(16,674 |
) |
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|
(7,835 |
) |
Other, net |
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731 |
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|
(126 |
) |
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|
3,593 |
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|
(18 |
) |
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|
|
|
|
|
|
|
|
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|
(11,105 |
) |
|
|
(2,103 |
) |
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|
(12,425 |
) |
|
|
(6,111 |
) |
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|
|
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|
Income from continuing operations before income taxes |
|
|
33,592 |
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|
|
1,396 |
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|
27,885 |
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|
42,378 |
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|
|
|
|
|
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|
|
|
|
|
|
|
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|
Provision (benefit) for income taxes |
|
|
(2,687 |
) |
|
|
(659 |
) |
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|
(5,074 |
) |
|
|
13,257 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations |
|
|
36,279 |
|
|
|
2,055 |
|
|
|
32,959 |
|
|
|
29,121 |
|
Loss from discontinued operations net of provision for
income taxes |
|
|
(578 |
) |
|
|
(27 |
) |
|
|
(1,324 |
) |
|
|
(1,527 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income |
|
|
35,701 |
|
|
|
2,028 |
|
|
|
31,635 |
|
|
|
27,594 |
|
Less: Income attributable to noncontrolling interest |
|
|
(293 |
) |
|
|
(372 |
) |
|
|
(902 |
) |
|
|
(1,543 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income attributable to Willbros Group, Inc. |
|
$ |
35,408 |
|
|
$ |
1,656 |
|
|
$ |
30,733 |
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|
$ |
26,051 |
|
|
|
|
|
|
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Reconciliation of net income attributable to Willbros Group, Inc. |
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|
|
|
|
|
|
|
|
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Income from continuing operations |
|
$ |
35,986 |
|
|
$ |
1,683 |
|
|
$ |
32,057 |
|
|
$ |
27,578 |
|
Loss from discontinued operations |
|
|
(578 |
) |
|
|
(27 |
) |
|
|
(1,324 |
) |
|
|
(1,527 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income attributable to Willbros Group, Inc. |
|
$ |
35,408 |
|
|
$ |
1,656 |
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|
$ |
30,733 |
|
|
$ |
26,051 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic income (loss) per share attributable to Company Shareholders: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations |
|
$ |
0.77 |
|
|
$ |
0.04 |
|
|
$ |
0.77 |
|
|
$ |
0.71 |
|
Loss from discontinued operations |
|
|
(0.01 |
) |
|
|
|
|
|
|
(0.03 |
) |
|
|
(0.04 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income |
|
$ |
0.76 |
|
|
$ |
0.04 |
|
|
$ |
0.74 |
|
|
$ |
0.67 |
|
|
|
|
|
|
|
|
|
|
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|
|
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Diluted income (loss) per share attributable to Company Shareholders: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations |
|
$ |
0.71 |
|
|
$ |
0.04 |
|
|
$ |
0.76 |
|
|
$ |
0.71 |
|
Loss from discontinued operations |
|
|
(0.01 |
) |
|
|
|
|
|
|
(0.03 |
) |
|
|
(0.04 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Income |
|
$ |
0.70 |
|
|
$ |
0.04 |
|
|
$ |
0.73 |
|
|
$ |
0.67 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average number of common shares outstanding: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic |
|
|
46,997,431 |
|
|
|
38,721,586 |
|
|
|
41,651,994 |
|
|
|
38,656,656 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted |
|
|
52,154,029 |
|
|
|
38,918,933 |
|
|
|
44,890,005 |
|
|
|
38,817,411 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to condensed consolidated financial statements.
4
WILLBROS GROUP, INC.
CONDENSED CONSOLIDATED STATEMENT OF STOCKHOLDERS EQUITY
AND COMPREHENSIVE INCOME (LOSS)
(In thousands, except share and per share amounts)
(Unaudited)
|
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|
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|
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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|
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|
|
|
|
|
|
|
|
Accumulated |
|
|
Total |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other |
|
|
Stockholders |
|
|
|
|
|
|
Total |
|
|
|
|
|
|
|
|
|
|
|
Capital in |
|
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|
|
|
|
|
|
|
|
Comprehensive |
|
|
Equity |
|
|
Non- |
|
|
Stock- |
|
|
|
Common Stock |
|
|
Excess of |
|
|
Accumulated |
|
|
Treasury |
|
|
Income |
|
|
Willbros |
|
|
controlling |
|
|
holders |
|
|
|
Shares |
|
|
Par |
|
|
Par Value |
|
|
Deficit |
|
|
Stock |
|
|
(Loss) |
|
|
Group, Inc. |
|
|
Interest |
|
|
Equity |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance, December 31, 2009 |
|
|
40,106,498 |
|
|
$ |
2,005 |
|
|
$ |
607,299 |
|
|
$ |
(124,788 |
) |
|
$ |
(9,045 |
) |
|
$ |
11,725 |
|
|
$ |
487,196 |
|
|
$ |
799 |
|
|
$ |
487,995 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
30,733 |
|
|
|
|
|
|
|
|
|
|
|
30,733 |
|
|
|
902 |
|
|
|
31,635 |
|
Foreign currency translation adjustment |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,407 |
|
|
|
2,407 |
|
|
|
|
|
|
|
2,407 |
|
Derivatives |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(711 |
) |
|
|
(711 |
) |
|
|
|
|
|
|
(711 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total comprehensive income (loss) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
32,429 |
|
|
|
|
|
|
|
33,331 |
|
Dividend declared and distributed to noncontrolling interest |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(942 |
) |
|
|
(942 |
) |
Amortization of stock-based compensation |
|
|
|
|
|
|
|
|
|
|
6,489 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6,489 |
|
|
|
|
|
|
|
6,489 |
|
Stock-based compensation tax benefit |
|
|
|
|
|
|
|
|
|
|
(956 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(956 |
) |
|
|
|
|
|
|
(956 |
) |
Stock issued under share-based plans |
|
|
437,274 |
|
|
|
19 |
|
|
|
(19 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock issued in connection with acquisition of InfrastruX |
|
|
7,923,308 |
|
|
|
396 |
|
|
|
57,682 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
58,078 |
|
|
|
|
|
|
|
58,078 |
|
Additions to treasury stock, vesting and forfeitures of restricted stock |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(894 |
) |
|
|
|
|
|
|
(894 |
) |
|
|
|
|
|
|
(894 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance, September 30, 2010 |
|
|
48,467,080 |
|
|
$ |
2,420 |
|
|
$ |
670,495 |
|
|
$ |
(94,055 |
) |
|
$ |
(9,939 |
) |
|
$ |
13,421 |
|
|
$ |
582,342 |
|
|
$ |
759 |
|
|
$ |
583,101 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to condensed consolidated financial statements.
5
WILLBROS GROUP, INC.
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands, except share and per share amounts)
(Unaudited)
|
|
|
|
|
|
|
|
|
|
|
Nine Months |
|
|
|
Ended September 30, |
|
|
|
2010 |
|
|
2009 |
|
Cash flows from operating activities: |
|
|
|
|
|
|
|
|
Net income (loss) |
|
$ |
31,635 |
|
|
$ |
27,594 |
|
Adjustments to reconcile net income (loss) to net cash provided by (used in)
operating activities: |
|
|
|
|
|
|
|
|
Loss from discontinued operations |
|
|
1,324 |
|
|
|
1,527 |
|
Depreciation and amortization |
|
|
36,374 |
|
|
|
31,082 |
|
Goodwill impairment |
|
|
12,000 |
|
|
|
|
|
Changes in fair value of contingent earnout liabilty |
|
|
(45,340 |
) |
|
|
|
|
Stock-based compensation |
|
|
6,489 |
|
|
|
9,321 |
|
Deferred income tax provision |
|
|
(7,437 |
) |
|
|
(2,485 |
) |
Other non-cash |
|
|
5,181 |
|
|
|
5,428 |
|
Changes in operating assets and liabilities: |
|
|
|
|
|
|
|
|
Accounts receivable, net |
|
|
(78,919 |
) |
|
|
38,717 |
|
Contract cost and recognized income not yet billed |
|
|
12,116 |
|
|
|
27,913 |
|
Prepaid expenses and other assets |
|
|
16,126 |
|
|
|
4,998 |
|
Accounts payable and accrued liabilities |
|
|
12,694 |
|
|
|
(64,967 |
) |
Accrued income taxes |
|
|
8,911 |
|
|
|
(5,511 |
) |
Contract billings in excess of cost and recognized income |
|
|
6,714 |
|
|
|
5,317 |
|
Other liabilities |
|
|
(228 |
) |
|
|
2,296 |
|
|
|
|
|
|
|
|
Cash provided by operating activities of continuing
operations |
|
|
17,640 |
|
|
|
81,230 |
|
Cash used in operating activities of
discontinued operations |
|
|
(533 |
) |
|
|
(222 |
) |
|
|
|
|
|
|
|
Cash provided by operating activities |
|
|
17,107 |
|
|
|
81,008 |
|
Cash flows from investing activities: |
|
|
|
|
|
|
|
|
Acquisition of subsidiaries, net of cash acquired and earnout |
|
|
(421,182 |
) |
|
|
(13,955 |
) |
Proceeds from sales of property, plant and equipment |
|
|
2,320 |
|
|
|
8,233 |
|
Purchases of property, plant and equipment |
|
|
(13,723 |
) |
|
|
(10,369 |
) |
Maturities of short-term investments |
|
|
16,755 |
|
|
|
|
|
Purchase of short-term investments |
|
|
(255 |
) |
|
|
|
|
|
|
|
|
|
|
|
Cash used in investing activities of continuing
operations |
|
|
(416,085 |
) |
|
|
(16,091 |
) |
Cash provided by investing activities of discontinued
operations |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash used in investing activities |
|
|
(416,085 |
) |
|
|
(16,091 |
) |
Cash flows from financing activities: |
|
|
|
|
|
|
|
|
Proceeds from term loan issuance |
|
|
282,000 |
|
|
|
|
|
Proceeds from stock issuance |
|
|
58,078 |
|
|
|
|
|
Payments on capital leases |
|
|
(5,690 |
) |
|
|
(20,326 |
) |
Repayment of notes payable |
|
|
(8,326 |
) |
|
|
(1,062 |
) |
Payments to reacquire common stock |
|
|
(894 |
) |
|
|
(483 |
) |
Payments on government fines |
|
|
(6,575 |
) |
|
|
(6,575 |
) |
Costs of debt issues |
|
|
(16,384 |
) |
|
|
(150 |
) |
Proceeds from exercise of stock options |
|
|
|
|
|
|
185 |
|
Stock-based compensation tax deficiency |
|
|
(956 |
) |
|
|
(1,655 |
) |
Dividend distribution to noncontrolling interest |
|
|
(942 |
) |
|
|
(2,137 |
) |
|
|
|
|
|
|
|
Cash provided by (used in) financing activities of continuing operations |
|
|
300,311 |
|
|
|
(32,203 |
) |
Cash provided by (used in) financing activities of discontinued operations |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash provided by (used in) financing activities |
|
|
300,311 |
|
|
|
(32,203 |
) |
|
|
|
|
|
|
|
Effect of exchange rate changes on cash and cash equivalents |
|
|
780 |
|
|
|
3,145 |
|
|
|
|
|
|
|
|
Cash provided by (used in) all activities |
|
|
(97,887 |
) |
|
|
35,859 |
|
Cash and cash equivalents, beginning of period |
|
|
198,774 |
|
|
|
207,864 |
|
|
|
|
|
|
|
|
Cash and cash equivalents, end of period |
|
$ |
100,887 |
|
|
$ |
243,723 |
|
|
|
|
|
|
|
|
Supplemental disclosures of cash flow information: |
|
|
|
|
|
|
|
|
Cash paid for interest |
|
$ |
9,007 |
|
|
$ |
4,648 |
|
Cash paid for income taxes (including discontinued operations) |
|
$ |
3,180 |
|
|
$ |
19,481 |
|
Supplemental non-cash investing and financing transactions: |
|
|
|
|
|
|
|
|
Initial contingent earnout liability |
|
$ |
55,340 |
|
|
$ |
|
|
Prepaid insurance obtained by note payable |
|
$ |
11,687 |
|
|
$ |
|
|
Equipment received through like-kind exchange |
|
$ |
3,355 |
|
|
$ |
|
|
Equipment surrendered through like-kind exchange |
|
$ |
2,550 |
|
|
$ |
|
|
See accompanying notes to condensed consolidated financial statements.
6
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
1. The Company and Basis of Presentation
Willbros Group, Inc., a Delaware corporation, and all of its majority-owned subsidiaries (the
Company, Willbros or WGI) is an independent international contractor serving the oil, gas and
power industries; government entities; and the refinery and petrochemical industries. The Companys
principal markets for continuing operations are the United States, Canada, and Oman. The Company
obtains its work through competitive bidding and through negotiations with prospective clients.
Contract values range from several thousand dollars to several hundred million dollars and contract
durations range from a few weeks to more than two years.
The accompanying Condensed Consolidated Balance Sheet as of December 31, 2009, which has been
derived from audited consolidated financial statements, and the unaudited interim Condensed
Consolidated Financial Statements as of September 30, 2009 and 2010, have been prepared pursuant to
the rules and regulations of the Securities and Exchange Commission (SEC). Accordingly, certain
information and note disclosures normally included in annual financial statements prepared in
accordance with generally accepted accounting principles have been condensed or omitted pursuant to
those rules and regulations. However, the Company believes the presentations and disclosures herein
are adequate to make the information not misleading. Certain prior period amounts have been
reclassified to be consistent with the current presentation. These unaudited Condensed Consolidated
Financial Statements should be read in conjunction with the Companys December 31, 2009 audited
Consolidated Financial Statements and notes thereto contained in the Companys Annual Report on
Form 10-K for the year ended December 31, 2009.
In the opinion of management, the unaudited Condensed Consolidated Financial Statements
reflect all adjustments necessary to present fairly the financial position as of September 30,
2010, the results of operations, statement of stockholders equity and cash flows of the Company
for all interim periods presented. The results of operations and cash flows for the three months
ended September 30, 2010 are not necessarily indicative of the operating results and cash flows to
be achieved for the full year.
The Condensed Consolidated Financial Statements include certain estimates and assumptions made
by management. These estimates and assumptions relate to the reported amounts of assets and
liabilities at the dates of the Condensed Consolidated Financial Statements and the reported
amounts of revenue and expense during the periods. Significant items subject to such estimates and
assumptions include the carrying amount of property, plant and equipment, goodwill and parts and
supplies inventories; quantification of amounts recorded for contingencies, tax accruals and
certain other accrued liabilities; valuation allowances for accounts receivable and deferred income
tax assets; and revenue recognition under the percentage-of-completion method of accounting,
including estimates of progress toward completion and estimates of gross profit or loss accrual on
contracts in progress. The Company bases its estimates on historical experience and other
assumptions that it believes relevant under the circumstances. Actual results could differ from
those estimates.
As discussed in Note 19 Discontinuance of Operations, Asset Disposals, and Transition
Services Agreement, the Company has disposed of certain assets and operations that are together
classified as discontinued operations (collectively the Discontinued Operations). Accordingly,
these Condensed Consolidated Financial Statements reflect these operations as discontinued
operations in all periods presented. The disclosures in the Notes to the Condensed Consolidated
Financial Statements relate to continuing operations except as otherwise indicated.
The carrying value of financial instruments does not materially differ from fair value.
Change in Estimate The Company performed a review of the estimated useful lives of certain
fixed assets at its Upstream Oil and Gas segment during the first quarter of 2010. This evaluation
indicated that actual lives for the construction equipment were generally longer than the estimated
useful lives used for depreciation purposes in the Companys financial statements. As a result, the
Company adjusted the estimated useful life on construction equipment from a range of four to six
years to a range of four to twelve years. The effect of this change in estimate was to reduce
depreciation expense for the three and nine months ended September 30, 2010 by $1,606 and $4,818,
respectively, and increase income from continuing operations by $1,044 and $3,132, net of taxes, or
$0.02 and $0.08 per basic share, respectively.
7
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
1. The Company and Basis of Presentation (continued)
Consistency Effective January 1, 2010, the Company has reclassified certain indirect
overhead expenses to general and administrative expenses to apply a consistent approach in the
classification of overhead across the legacy business segments. If the Company reclassified these
same costs in the three-month and nine-month periods ended September 30, 2009, the reported general
and administrative costs would have increased, accompanied by a corresponding decrease to contract
costs of $1,258 and $4,042, respectively. The Company is currently in the process of evaluating the
impact, if any, that the treatment of these costs would have on the Utility Transmission &
Distribution (Utility T&D) segment.
Warranty Costs In connection with the acquisition of InfrastruX Group, Inc. (InfrastruX),
the Company warrants labor for new installations and construction and servicing of existing
infrastructure. The anticipated costs are not considered significant and no reserve has been
provided. One of the InfrastruX subsidiary companies maintains a warranty program which
specifically covers its cable remediation services. A warranty reserve of $2,443 for cable
remediation services is recorded in Other long-term liabilities on the balance sheet as of
September 30, 2010. Prior to the acquisition of InfrastruX, the Company has historically recorded
an immaterial amount related to warranty reserve.
Property, Plant and Equipment In connection with the acquisition of InfrastruX, the Company
acquired $156,160 of property, plant and equipment. Depreciation, including amortization of
capital leases, is provided on the straight-line method using the estimated lives as follows:
|
|
|
|
|
Construction equipment |
|
3-20 years |
|
|
|
|
|
Furniture and equipment |
|
3-12 years |
|
|
|
|
|
Buildings |
|
20 years |
|
|
|
|
|
Transportation equipment |
|
3-17 years |
|
|
|
|
|
Aircraft and marine equipment |
|
10 years |
The table has been updated from the Companys Annual Report on Form 10-K for the year ended
December 31, 2009 to reflect the estimated useful lives of the assets acquired.
2. New Accounting Pronouncements
In June 2009, the FASB issued a new accounting standard which provides amendments to previous
guidance on the consolidation of variable interest entities (VIE). This standard clarifies the
characteristics that identify a VIE and changes how a reporting entity identifies a primary
beneficiary that would consolidate the VIE from a quantitative risk and rewards calculation to a
qualitative approach based on which variable interest holder has controlling financial interest and
the ability to direct the most significant activities that impact the VIEs economic performance.
This statement requires the primary beneficiary assessment to be performed on a continuous basis.
It also requires additional disclosures about an entitys involvement with a VIE, restrictions on
the VIEs assets and liabilities that are included in the reporting entitys consolidated balance
sheet, significant risk exposures due to the entitys involvement with the VIE, and how its
involvement with a VIE impacts the reporting entitys consolidated financial statements. The
standard was effective for fiscal years beginning after November 15, 2009. The adoption of the
standard did not have any impact on the Companys consolidated financial statements.
3. Acquisition
On July 1, 2010, the Company completed the acquisition of 100 percent of the outstanding stock
of InfrastruX for a purchase price of $485,800, before final working capital and other transaction
adjustments. The Company paid $372,382 in cash, a portion of which was used to retire InfrastruX
indebtedness and pay InfrastruX transaction expenses, and issued approximately 7.9 million shares
of the Companys common stock to the shareholders of InfrastruX. Cash paid was comprised of $72,382
in cash from operations and $300,000 from a new term loan facility. The acquisition was completed
pursuant to an Agreement and Plan of Merger (the Merger), dated March 11, 2010.
Under the agreement, InfrastruX shareholders are eligible to receive earnout payments of up to
$125,000 if certain EBITDA targets are met. Refer to Note 17 Fair Value Measurements for further
discussion of the contingent earnout.
8
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
3. Acquisition (continued)
InfrastruX was a privately-held firm based in Seattle, Washington and provides design,
construction, maintenance, engineering and other infrastructure services to the utility industry
across the U.S. market. This acquisition provides the Company the opportunity to strengthen its
presence in the infrastructure markets within the utility industry.
Consideration
Total consideration transferred in acquiring InfrastruX is summarized as follows:
|
|
|
|
|
Proceeds from newly issued term loan facility |
|
$ |
300,000 |
|
|
|
|
|
|
Cash provided from operations |
|
|
72,382 |
|
|
|
|
|
|
|
|
|
|
Total cash consideration |
|
|
372,382 |
|
|
|
|
|
|
Issuance of WG common stock |
|
|
58,078 |
(1) |
|
|
|
|
|
Contingent consideration |
|
|
55,340 |
(2) |
|
|
|
|
|
|
|
|
|
Total Consideration |
|
$ |
485,800 |
|
|
|
|
|
|
|
|
(1) |
|
Represents 7,923,308 shares issued, which have been valued at the closing price of
Company stock on July 1, 2010, the acquisition date. |
|
(2) |
|
Estimated as of acquisition
announcement date based on a probability estimate of InfrastruXs EBITDA
achievements during the earnout period. |
This transaction has been accounted for using the acquisition method of accounting which
requires that, among other things, assets acquired and liabilities assumed be recorded at their
fair values as of the acquisition date. The excess of the consideration transferred over those fair
values is recorded as goodwill. The preliminary allocation of purchase
price to acquired assets and liabilities is as follows:
|
|
|
|
|
Assets acquired: |
|
|
|
|
Cash and cash equivalents |
|
$ |
9,278 |
|
Accounts receivable |
|
|
124,856 |
|
Inventories |
|
|
4,501 |
|
Prepaid expenses and other current assets |
|
|
39,565 |
|
Property, plant and equipment |
|
|
156,160 |
|
Intangible assets |
|
|
170,790 |
|
Goodwill |
|
|
184,376 |
|
Other long-term assets |
|
|
19,989 |
|
Liabilities assumed: |
|
|
|
|
Accounts Payable and other accrued liabilities |
|
|
(97,985 |
) |
Capital Lease Obligations |
|
|
(4,977 |
) |
Vendor related debt |
|
|
(2,761 |
) |
Deferred income taxes and other tax liabilities |
|
|
(95,902 |
) |
Other long-term liabilities |
|
|
(22,090 |
) |
|
|
|
|
Net Assets Acquired |
|
$ |
485,800 |
|
|
|
|
|
The Company has consolidated InfrastruX in its financial results as the Utility T&D segment
from the date of the acquisition. Our purchase price allocation has not been finalized due to the
ongoing negotiation of closing working capital and other closing adjustments. These are expected to
be finalized during the fourth quarter of 2010. However, under U.S. GAAP, companies have up to one year
after an acquisition to finalize the acquisition accounting.
Property, plant and equipment (PP&E)
A step-up adjustment of $25,077 was recorded to present the PP&E acquired at its estimated
fair value. The weighted average useful life used to calculate depreciation of the step up related
to PP&E is approximately seven years.
9
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
3. Acquisition (continued)
Intangible assets
The following table summarizes the fair value estimates recorded for the identifiable
intangible assets and their estimated useful lives:
|
|
|
|
|
|
|
|
|
|
|
Estimated Fair Value |
|
|
Estimated Useful Life |
|
Trade Name |
|
$ |
12,700 |
|
|
10 years |
Customer Relationships |
|
|
152,890 |
|
|
15 years |
Technology |
|
|
5,200 |
|
|
10 years |
|
|
|
|
|
|
|
|
Total Identifiable Intangible Assets |
|
$ |
170,790 |
|
|
|
|
|
|
|
|
|
|
|
|
|
The amortizable intangible assets have useful lives ranging between ten years and fifteen
years and a weighted average useful life of 14.2 years. Goodwill represents the excess of the
purchase price over the fair value of the net tangible and identifiable intangible assets acquired.
Goodwill associated with this transaction is not expected to be deductible for tax purposes. The
goodwill recorded in connection with this acquisition is included in the Utility T&D segment.
Deferred taxes
The Company provided deferred taxes and other tax liabilities as part of the acquisition
accounting related to the estimated fair market value adjustments for acquired intangible assets
and PP&E. An adjustment of $95,902 was recorded to present the deferred taxes and other tax
liabilities at fair value.
Pro Forma Impact of the Acquisition
The following unaudited supplemental pro forma results present consolidated information as if
the acquisition had been completed as of January 1, 2010 and January 1, 2009. The pro forma results
include: (i) the amortization associated with an estimate of the acquired intangible assets, (ii)
interest expense associated with debt used to fund a portion of the acquisition and reduced
interest income associated with cash used to fund a portion of the acquisition, (iii) the impact of
certain fair value adjustments such as additional depreciation expense for adjustments to property,
plant and equipment and reduction to interest expense for adjustments to debt, and (iv) costs
directly related to acquiring InfrastruX. The pro forma results do not include any potential
synergies, cost savings or other expected benefits of the acquisition. Accordingly, the pro forma
results should not be considered indicative of the results that would have occurred if the
acquisition and related borrowings had been consummated as of January 1, 2009, or January 1, 2010,
nor are they indicative of future results.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
Nine Months Ended |
|
|
|
September 30, |
|
|
September 30, |
|
|
|
2010 |
|
|
2009 |
|
|
2010 |
|
|
2009 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues |
|
$ |
408,792 |
|
|
$ |
401,410 |
|
|
$ |
1,102,333 |
|
|
$ |
1,536,606 |
|
Net income (loss) attributable to
Company shareholders |
|
$ |
35,986 |
|
|
$ |
(8,108 |
) |
|
$ |
12,008 |
|
|
$ |
764 |
|
Basic net income (loss) per share |
|
$ |
0.77 |
|
|
$ |
(0.17 |
) |
|
$ |
0.29 |
|
|
$ |
0.02 |
|
Diluted net income (loss) per share |
|
$ |
0.71 |
|
|
$ |
(0.17 |
) |
|
$ |
0.29 |
|
|
$ |
0.02 |
|
10
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
4. Accounts Receivable
Accounts receivable, net as of September 30, 2010 and December 31, 2009 is comprised of the
following:
|
|
|
|
|
|
|
|
|
|
|
September 30, |
|
|
December 31, |
|
|
|
2010 |
|
|
2009 |
|
|
|
|
|
|
|
|
|
|
Trade |
|
$ |
284,569 |
|
|
$ |
105,858 |
|
Unbilled revenue |
|
|
61,092 |
|
|
|
18,314 |
|
Contract retention |
|
|
21,773 |
|
|
|
38,357 |
|
Other receivables |
|
|
1,280 |
|
|
|
1,867 |
|
|
|
|
|
|
|
|
Total accounts receivable |
|
|
368,714 |
|
|
|
164,396 |
|
Less: allowance for doubtful accounts |
|
|
(2,326 |
) |
|
|
(1,936 |
) |
|
|
|
|
|
|
|
Total accounts receivable, net |
|
$ |
366,388 |
|
|
$ |
162,460 |
|
|
|
|
|
|
|
|
The Company expects all accounts receivable to be collected within one year. The provision for
bad debts included in General and administrative expenses in the Consolidated Statements of
Income was $630 and $664 for the nine months ended September 30, 2010 and year ended December
31, 2009, respectively.
5. Contracts in Progress
Contract cost and recognized income not yet billed on uncompleted contracts arise when
revenues have been recorded but the amounts cannot be billed under the terms of the contracts.
Contract billings in excess of cost and recognized income arise when billed amounts exceed revenues
recorded. Amounts are billable to customers upon various measures of performance, including
achievement of certain milestones, completion of specified units or completion of the contract.
Also included in contract cost and recognized income not yet billed on uncompleted contracts are
amounts the Company seeks to collect from customers for change orders approved in scope but not for
price associated with that scope change (unapproved change orders). Revenue for these amounts is
recorded equal to cost incurred when realization of price approval is probable and the estimated
amount is equal to or greater than the Companys cost related to the unapproved change order.
Unapproved change orders involve the use of estimates, and it is reasonably possible that revisions
to the estimated recoverable amounts of recorded unapproved change orders may be made in the
near-term. If the Company does not successfully resolve these matters, a reduction in revenues may
be required to amounts that have been previously recorded.
Contract cost and recognized income not yet billed and related amounts billed as of September
30, 2010 and December 31, 2009 was as follows:
|
|
|
|
|
|
|
|
|
|
|
September 30, |
|
|
December 31, |
|
|
|
2010 |
|
|
2009 |
|
|
|
|
|
|
|
|
|
|
Cost incurred on contracts in progress |
|
$ |
983,639 |
|
|
$ |
1,113,712 |
|
Recognized income |
|
|
207,266 |
|
|
|
161,398 |
|
|
|
|
|
|
|
|
|
|
|
1,190,905 |
|
|
|
1,275,110 |
|
Progress billings and advance payments |
|
|
(1,175,978 |
) |
|
|
(1,241,437 |
) |
|
|
|
|
|
|
|
|
|
$ |
14,927 |
|
|
$ |
33,673 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Contract cost and recognized income not yet billed |
|
$ |
32,986 |
|
|
$ |
45,009 |
|
Contract billings in excess of cost and recognized income |
|
|
(18,059 |
) |
|
|
(11,336 |
) |
|
|
|
|
|
|
|
|
|
$ |
14,927 |
|
|
$ |
33,673 |
|
|
|
|
|
|
|
|
Contract cost and recognized income not yet billed includes $13,556 and $1,551 at September
30, 2010, and December 31, 2009, respectively, on completed contracts.
11
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
6. Property, Plant and Equipment
Property, plant and equipment, at cost, which are used to secure debt or are subject to lien,
as of September 30, 2010 and December 31, 2009 were as follows:
|
|
|
|
|
|
|
|
|
|
|
September 30, |
|
|
December 31, |
|
|
|
2010 |
|
|
2009 |
|
|
|
|
|
|
|
|
|
|
Construction equipment |
|
$ |
175,562 |
|
|
$ |
140,157 |
|
Furniture and equipment |
|
|
50,566 |
|
|
|
44,119 |
|
Land and buildings |
|
|
41,999 |
|
|
|
36,278 |
|
Transportation equipment |
|
|
149,238 |
|
|
|
32,264 |
|
Leasehold improvements |
|
|
17,718 |
|
|
|
16,221 |
|
Aircraft |
|
|
7,410 |
|
|
|
7,410 |
|
Marine equipment |
|
|
120 |
|
|
|
120 |
|
|
|
|
|
|
|
|
Total property, plant and equipment |
|
|
442,613 |
|
|
|
276,569 |
|
Less: accumulated depreciation |
|
|
(170,107 |
) |
|
|
(143,690 |
) |
|
|
|
|
|
|
|
Total property, plant and equipment, net |
|
$ |
272,506 |
|
|
$ |
132,879 |
|
|
|
|
|
|
|
|
Amounts above include $7,138 and $4,401 of construction in progress as of September 30, 2010
and December 31, 2009, respectively. Depreciation expense included in operating expense for the
nine months ended September 30, 2010 and the year ended December 31, 2009 was $30,548 and $34,345,
respectively.
7. Goodwill and Other Intangible Assets
The changes in the carrying amount of goodwill for the nine months ended September 30, 2010,
by business segment, are detailed below:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Impairment |
|
|
|
|
Upstream Oil & Gas |
|
Goodwill |
|
|
Reserves |
|
|
Total, Net |
|
Balance as of January 1, 2009 |
|
$ |
11,142 |
|
|
$ |
|
|
|
$ |
11,142 |
|
Goodwill from acquisitions |
|
|
|
|
|
|
|
|
|
|
|
|
Purchase price adjustments |
|
|
|
|
|
|
|
|
|
|
|
|
Impairment losses |
|
|
|
|
|
|
|
|
|
|
|
|
Translation adjustments and other |
|
|
1,496 |
|
|
|
|
|
|
|
1,496 |
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2009 |
|
|
12,638 |
|
|
|
|
|
|
|
12,638 |
|
Goodwill from acquisitions |
|
|
|
|
|
|
|
|
|
|
|
|
Purchase price adjustments |
|
|
|
|
|
|
|
|
|
|
|
|
Impairment losses |
|
|
|
|
|
|
|
|
|
|
|
|
Translation adjustments and other |
|
|
207 |
|
|
|
|
|
|
|
207 |
|
|
|
|
|
|
|
|
|
|
|
Balance as of September 30, 2010 |
|
$ |
12,845 |
|
|
$ |
|
|
|
$ |
12,845 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Impairment |
|
|
|
|
Downstream Oil & Gas |
|
Goodwill |
|
|
Reserves |
|
|
Total, Net |
|
Balance as of January 1, 2009 |
|
$ |
131,518 |
|
|
$ |
(62,295 |
) |
|
$ |
69,223 |
|
Goodwill from acquisitions |
|
|
3,600 |
|
|
|
|
|
|
|
3,600 |
|
Purchase price adjustments |
|
|
299 |
|
|
|
|
|
|
|
299 |
|
Impairment losses |
|
|
|
|
|
|
|
|
|
|
|
|
Translation adjustments and other |
|
|
15 |
|
|
|
|
|
|
|
15 |
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2009 |
|
|
135,432 |
|
|
|
(62,295 |
) |
|
|
73,137 |
|
Goodwill from acquisitions |
|
|
|
|
|
|
|
|
|
|
|
|
Purchase price adjustments |
|
|
617 |
|
|
|
|
|
|
|
617 |
|
Impairment losses |
|
|
|
|
|
|
(12,000 |
) |
|
|
(12,000 |
) |
Translation adjustments and other |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of September 30, 2010 |
|
$ |
136,049 |
|
|
$ |
(74,295 |
) |
|
$ |
61,754 |
|
|
|
|
|
|
|
|
|
|
|
12
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
7. Goodwill and Other Intangible Assets (continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Impairment |
|
|
|
|
Utility T&D |
|
Goodwill |
|
|
Reserves |
|
|
Total, Net |
|
Balance as of July 1, 2010 |
|
$ |
184,376 |
|
|
$ |
|
|
|
$ |
184,376 |
|
Purchase price adjustments |
|
|
|
|
|
|
|
|
|
|
|
|
Impairment losses |
|
|
|
|
|
|
|
|
|
|
|
|
Translation adjustments and other |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of September 30, 2010 |
|
$ |
184,376 |
|
|
$ |
|
|
|
$ |
184,376 |
|
|
|
|
|
|
|
|
|
|
|
According to accounting standards for goodwill, goodwill and other intangibles are required to
be evaluated whenever indicators of impairment exist and at least annually. The Company conducts
its annual evaluations during the fourth quarter. The standard requires a two-step process be
performed to analyze whether or not goodwill has been impaired. The first step of this test, used
to identify potential impairment, compares the estimated fair value of a reporting unit with its
carrying amount. The second step, if necessary, measures the amount of the impairment. Goodwill
and other purchased intangible assets are included in the identifiable assets of the segment to
which they have been assigned.
During the third quarter, in connection with the completion of the preliminary forecast for
2011, it became evident that a goodwill impairment at Downstream Oil & Gas was probable. As a
result, a preliminary step one analysis for that segment was performed. Using a discounted cash
flow analysis supported by comparative market multiples to determine the fair value of the segment
versus its carrying value, a range of likely impairment was generated. The low end of this range
was approximately $12,000. Accordingly, the Company recorded an impairment charge of $12,000
during the third quarter of 2010.
The third quarter charge was driven by reduced demand for services resulting from the current
low level of both capital and maintenance spending in the refining industry, which has fostered a
highly competitive environment, resulting in significantly decreased margins. The Company expects
to conclude the second step of the impairment test during the fourth
quarter of 2010. This
may result in further impairment.
The changes in the carrying amounts of intangible assets for the nine months ended September
30, 2010 are detailed below:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Customer |
|
|
Trademark / |
|
|
Non-compete |
|
|
|
|
|
|
|
|
|
Relationships |
|
|
Tradename |
|
|
Agreements |
|
|
Technology |
|
|
Total |
|
Balance as of December 31, 2009 |
|
$ |
34,547 |
|
|
$ |
1,235 |
|
|
$ |
990 |
|
|
$ |
|
|
|
$ |
36,772 |
|
Additions |
|
|
152,890 |
|
|
|
12,700 |
|
|
|
|
|
|
|
5,200 |
|
|
|
170,790 |
|
Amortization |
|
|
(5,116 |
) |
|
|
(415 |
) |
|
|
(165 |
) |
|
|
(130 |
) |
|
|
(5,826 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of September 30, 2010 |
|
$ |
182,321 |
|
|
$ |
13,520 |
|
|
$ |
825 |
|
|
$ |
5,070 |
|
|
$ |
201,736 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted Average Remaining
Amortization Period |
|
13.6 yrs |
|
|
9.7 yrs |
|
|
3.8 yrs |
|
|
9.8 yrs |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Intangible assets are amortized on a straight-line basis over their estimated useful lives,
which range from 5 to 15 years.
Amortization expense included in net income for the three and nine months ended September 30,
2010 was $3,921 and $5,826, respectively. Estimated amortization expense for the remainder of 2010
and each of the subsequent five years and thereafter is as follows:
|
|
|
|
|
Fiscal year: |
|
|
|
|
2010 |
|
$ |
3,948 |
|
2011 |
|
|
15,793 |
|
2012 |
|
|
15,793 |
|
2013 |
|
|
15,793 |
|
2014 |
|
|
15,683 |
|
2015 |
|
|
15,573 |
|
Thereafter |
|
|
119,153 |
|
|
|
|
|
Total amortization |
|
$ |
201,736 |
|
|
|
|
|
13
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
8. Accounts Payable and Accrued Liabilities
Accounts payable and accrued liabilities as of September 30, 2010 and December 31, 2009 were
as follows:
|
|
|
|
|
|
|
|
|
|
|
September 30, |
|
|
December 31, |
|
|
|
2010 |
|
|
2009 |
|
|
|
|
|
|
|
|
|
|
Trade accounts payable |
|
$ |
86,470 |
|
|
$ |
48,302 |
|
Payroll and payroll liabilities |
|
|
26,656 |
|
|
|
23,037 |
|
Provision for loss contract costs |
|
|
420 |
|
|
|
1,062 |
|
Other accrued liabilities |
|
|
79,027 |
|
|
|
9,420 |
|
|
|
|
|
|
|
|
Total accounts payable and accrued liabilities |
|
$ |
192,573 |
|
|
$ |
81,821 |
|
|
|
|
|
|
|
|
9. Government Obligations
Government obligations represent amounts due to government entities, specifically the United
States Department of Justice (DOJ) and the SEC, in final settlement of the investigations
involving violations of the Foreign Corrupt Practices Act (the FCPA) and violations of the
Securities Act of 1933 (the Securities Act) and the Securities Exchange Act of 1934 (the
Exchange Act). These investigations stem primarily from the Companys former operations in
Bolivia, Ecuador and Nigeria. In May 2008, the Company reached final agreements with the DOJ and
the SEC to settle their investigations. As previously disclosed, the agreements provided for an
aggregate payment of $32,300 including $22,000 in fines to the DOJ related to the FCPA violations,
consisting of $10,000 paid on signing and $4,000 annually for three years thereafter, with no
interest due on unpaid amounts and $10,300 to the SEC, consisting of $8,900 of profit disgorgement
and $1,400 of pre-judgment interest, payable in four equal installments of $2,575 with the first
installment paid on signing and annually for three years thereafter. Post-judgment interest is
payable on the outstanding $7,725.
During the twelve months ended December 31, 2008, $12,575 of the aggregate obligation was
paid, which consisted of the initial $10,000 payment to the DOJ and the first installment of $2,575
to the SEC, inclusive of all pre-judgment interest. During the twelve months ended December 31,
2009, $6,575 of the aggregate obligation was paid, which consisted of the $4,000 annual installment
to the DOJ and the $2,575 annual installment to the SEC, inclusive of all pre-judgment interest.
On May 24, 2010 and May 27, 2010, the Company made its third installment payments in the
amounts of $4,000 and $2,575, plus post judgment interest, to the DOJ and SEC, respectively. The
remaining aggregate obligation of $6,575 has been classified on the Consolidated Balance Sheets as
Current portion of government obligations. This amount is based on payment terms that provide
for one remaining equal installment of $2,575 and $4,000 to the SEC and DOJ, respectively, in 2011.
10. Long-term Debt
Long-term debt as of September 30, 2010 and December 31, 2009 was as follows:
|
|
|
|
|
|
|
|
|
|
|
September 30, |
|
|
December 31, |
|
|
|
2010 |
|
|
2009 |
|
|
|
|
|
|
|
|
|
|
Capital lease obligations |
|
$ |
15,975 |
|
|
$ |
16,516 |
|
Term loan |
|
|
282,904 |
|
|
|
|
|
2.75% convertible senior notes, net |
|
|
58,006 |
|
|
|
56,071 |
|
6.5% senior convertible notes, net |
|
|
31,895 |
|
|
|
31,450 |
|
Other obligations |
|
|
2,333 |
|
|
|
|
|
|
|
|
|
|
|
|
Total long-term debt |
|
|
391,113 |
|
|
|
104,037 |
|
Less: current portion |
|
|
(106,000 |
) |
|
|
(37,274 |
) |
|
|
|
|
|
|
|
Long-term debt, net |
|
$ |
285,113 |
|
|
$ |
66,763 |
|
|
|
|
|
|
|
|
14
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
10. Long-term Debt (continued)
2010 Credit Facility
The Company entered into a new credit agreement dated June 30, 2010 (the 2010 Credit
Agreement), among Willbros United States Holdings, Inc. (WUSH), a subsidiary of the Company
(formerly known as Willbros USA, Inc.) as borrower, the Company and certain of its subsidiaries, as
Guarantors, the lenders from time to time party thereto (the Lenders), Crédit Agricole Corporate
and Investment Bank (Crédit Agricole), as Administrative Agent, Collateral Agent, Issuing Bank,
Revolving Credit Facility Sole Lead Arranger, Sole Bookrunner and participating Lender, UBS
Securities LLC (UBS), as Syndication Agent, Natixis, The Bank of Nova Scotia and Capital One,
N.A., as Co-Documentation Agents, and Crédit Agricole and UBS as Term Loan Facility Joint Lead
Arrangers and Joint Bookrunners. The new 2010 Credit Agreement consists of a four year, $300,000
term loan facility (Term Loan) maturing in July 2014 and a three year revolving credit facility
of $175,000 maturing in July 2013 (the 2010 Credit
Facility) and replaced the Companys existing three-year $150,000 senior
secured credit facility, which was scheduled to expire in November 2010. The proceeds from the Term
Loan were used to pay part of the cash portion of the merger consideration payable in connection
with the Companys acquisition of InfrastruX.
The initial aggregate amount of commitments for the revolving credit facility totaled
$175,000, including an accordion feature enabling the Company to increase the size of the facility
by an incremental $75,000 if it is in compliance with certain terms of the 2010 Credit Facility.
The revolving credit facility is available for letters of credit and for revolving loans, which may
be used for working capital and general corporate purposes. During an interim period ending on
either September 30, 2010, if the Company is in compliance with end of 2010 leverage ratio
requirements, or December 31, 2010 (the Interim Period), the revolving credit facility has a
sublimit of $31,500 for revolving loans, with the proceeds thereof to be used only to pay the
purchase price on the Companys 6.5% Senior Convertible Notes (the 6.5% Notes) due 2012, as a
result of any holder thereof exercising its right to require the Company to purchase such notes.
Thereafter, the revolving credit facility will have a sublimit of $150,000 for revolving loans.
The Company is able to utilize 100 percent of the revolving credit facility to obtain letters
of credit, including during the Interim Period. As of
September 30 2010, the Company had not
borrowed any funds under the revolving credit facility.
Interest payable under the 2010 Credit Agreement is determined by the loan type. Base rate
loans require annual interest payments equal to the adjusted base rate plus the applicable margin
for base rate loans. The adjusted base rate is equal to the highest of (a) the Prime Rate in
effect for such day, (b) the sum of the Federal Funds Effective Rate in effect for such day plus
1/2 of 1.0% per annum, (c) the sum of the Prime, London Inter-Bank Offered Rate (LIBOR) or
Eurocurrency Rate in effect for such day with a maturity of one month plus 1.0% per annum and (d)
with respect to Term Loans only is 3.0% per annum. The applicable margin for base rate loans is
6.50% per annum for Term Loans and 3.25% per annum for revolving advances during the Interim Period
or following the Interim Period, a fixed margin based on the Companys leverage ratio.
Eurocurrency rate loans require annual interest payments equal to the Eurocurrency Rate plus the
applicable margin for Eurocurrency rate loans. The Eurocurrency Rate is equal to the LIBOR rate in
effect for such day, subject to a 2.0% floor for Term Loans only. The applicable margin for
Eurocurrency rate loans is 7.50% per annum for Term Loans and 4.25% per annum for revolving
advances during the Interim Period or following the Interim Period, a fixed margin based on the
Companys leverage ratio. As of September 30, 2010, the interest rate on the Term Loan (currently
a Eurocurrency rate loan) was 9.5%. Interest payments on the Eurocurrency rate loans are payable
in arrears on the last day of such interest period, and, in the case of interest periods of greater
than three months, on each business day which occurs at three month intervals from the first day of
such interest period. Interest payments on base rate loans are payable quarterly in arrears on the
last business day of each calendar quarter. Additionally, the Company is required under the terms
of the 2010 Credit Agreement to maintain in effect, one or more hedging arrangements to fix or
otherwise limit the interest cost with respect to at least 50 percent of the aggregate outstanding
principal amount of the Term Loan.
The Term Loan was issued at a discount such that the funded portion was equal to 94 percent of
the principal amount of the Term Loan. Accordingly, the Company recognized an $18,000 discount on
the Term Loan that is being amortized over the four-year term of the Term Loan.
The 2010 Credit Facility is secured by substantially all of the assets of WUSH, the Company
and the other Guarantors. The 2010 Credit Agreement prohibits the Company from paying cash
dividends on its common stock.
15
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
10. Long-term Debt (continued)
The 2010 Credit Agreement includes customary affirmative and negative covenants, including:
|
|
|
maintenance of a minimum interest coverage ratio; |
|
|
|
maintenance of a maximum total leverage ratio; |
|
|
|
maintenance of a minimum tangible net worth amount; |
|
|
|
maintenance of a minimum consolidated EBITDA and a minimum cash balance during the
Interim Period; |
|
|
|
limitations on capital expenditures during the Interim Period, $60,000, and the greater
of $70,000 or 25% of EBITDA thereafter; |
|
|
|
limitations on indebtedness; |
|
|
|
limitations on certain asset sales and dispositions; and |
|
|
|
limitations on certain acquisitions and asset purchases if certain liquidity levels are
not maintained. |
A default under the 2010 Credit Agreement may be triggered by events such as a failure to
comply with financial covenants or other covenants under the 2010 Credit Agreement, a failure to
make payments when due under the 2010 Credit Agreement, a failure to make payments when due in
respect of, or a failure to perform obligations relating to, debt obligations in excess of $15,000,
a change of control of the Company and certain insolvency proceedings. A default under the 2010
Credit Agreement would permit Crédit Agricole and the Lenders to terminate their commitment to make
cash advances or issue letters of credit, require the immediate repayment of any outstanding cash
advances with interest and require the cash collateralization of outstanding letter of credit
obligations. As of September 30, the Company was in compliance with all covenants under this
Agreement.
Incurred unamortized debt issue costs associated with the creation of the 2010 Credit
Agreement are $16,384. These debt issue costs are included in Other assets at September 30,
2010. These costs will be amortized to interest expense over the three and four-year terms of the
revolving credit facility and Term Loan, respectively.
2007 Credit Facility
On November 20, 2007, the Company entered into a credit agreement (the Credit Agreement),
among WUSH as borrower, the Company and certain of its subsidiaries as guarantors (collectively,
the Loan Parties), and a group of lenders (the Lenders) led by Calyon New York Branch
(Calyon). The Credit Agreement provided for a three-year senior secured $150,000 revolving credit
facility maturing in November 2010 (the 2007 Credit Facility). The Company was able to utilize
100 percent of the 2007 Credit Facility to obtain performance letters of credit and 33.3 percent
(or $50,000) of the facility for cash advances for general corporate purposes and financial letters
of credit. The 2007 Credit Facility was secured by substantially all of the assets of the Company,
including those of the Loan Parties, as well as a pledge of 100 percent of the equity interests of
WUSH and each of the Companys other material U.S. subsidiaries and 65.0 percent of the equity
interests of Willbros Global Holdings, Inc. On July 1, 2010, the 2007 Credit Facility was
terminated in connection with the acquisition of InfrastruX and replaced with the new 2010 Credit
Agreement.
6.5% Senior Convertible Notes
In December 2005, the Company completed a private placement of $65,000 aggregate principal
amount of its 6.5% Notes, pursuant to a purchase agreement (the Purchase Agreement). During the
first quarter of 2006, the initial purchasers of the 6.5% Notes exercised their options to purchase
an additional $19,500 aggregate principal amount of the 6.5% Notes. The primary offering and the
purchase option of the 6.5% Notes totaled $84,500.
The 6.5% Notes are governed by an indenture by and among the Company, as issuer, WUSH, as
guarantor, and Bank of Texas, N.A. (as successor to the original trustee), as Trustee (the
Indenture), and were issued under the Purchase Agreement by and among the Company and the initial
purchasers of the 6.5% Notes (the Purchasers), in a transaction exempt from the registration
requirements of the Securities Act of 1933, as amended. The 6.5% Notes are convertible into shares
of the Companys common stock at a conversion rate of 56.9606 shares of common stock per $1,000
principal amount of notes representing a conversion price of approximately $17.56 per share. If all
notes had been converted to common stock at September 30, 2010, 1,825,587 shares would have been
issuable based on the principal amount of the 6.5% Notes which remain
outstanding, subject to adjustment in certain circumstances. The 6.5% Notes are general senior
unsecured obligations. Interest is due semi-annually on June 15 and December 15.
16
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
10. Long-term Debt (continued)
The 6.5% Notes mature on December 15, 2012 unless the notes are repurchased or converted
earlier. The Company does not have the right to redeem the 6.5% Notes prior to maturity. Upon
maturity, the principal amount plus the accrued interest through the day prior to the maturity date
is payable only in cash. The holders of the 6.5% Notes have the right to require the Company to
purchase the 6.5% Notes for cash, including unpaid interest, on December 15, 2010. The holders of
the 6.5% Notes also have the right to require the Company to purchase the 6.5% Notes for cash upon
the occurrence of a fundamental change, as defined in the Indenture. In addition to the amounts
described above, the Company will be required to pay a make-whole premium to the holders of the
6.5% Notes who elect to convert their notes into the Companys common stock in connection with a
fundamental change. The make-whole premium is payable in additional shares of common stock and is
calculated based on a formula with the premium ranging from 0.0 percent to 28.0 percent depending
on when the fundamental change occurs and the price of the Companys stock at the time the
fundamental change occurs. Based on the uncertainty surrounding the future economic conditions, the
Company is unable to estimate the number or probability of future repurchases of the 6.5% Notes on
December 15, 2010. As such, all $31,450 (net of $600 bond discount) and $31,895 (net of $155 bond
discount) has been classified as short-term and included within Notes payable and current portion
of other long-term debt on the Consolidated Balance Sheet at December 31, 2009 and September 30,
2010, respectively.
Upon conversion of the 6.5% Notes, the Company has the right to deliver, in lieu of shares of
its common stock, cash or a combination of cash and shares of its common stock. Under the
Indenture, the Company is required to notify holders of the 6.5% Notes of its method for settling
the principal amount of the 6.5% Notes upon conversion. This notification, once provided, is
irrevocable and legally binding upon the Company with regard to any conversion of the 6.5% Notes.
On March 21, 2006, the Company notified holders of the 6.5% Notes of its election to satisfy its
conversion obligation with respect to the principal amount of any 6.5% Notes surrendered for
conversion by paying the holders of such surrendered 6.5% Notes 100 percent of the principal
conversion obligation in the form of common stock of the Company. Until the 6.5% Notes are
surrendered for conversion, the Company will not be required to notify holders of its method for
settling the excess amount of the conversion obligation relating to the amount of the conversion
value above the principal amount, if any. In the event of a payment default or other default which
results in acceleration on any credit agreement of $10,000 or more,
including the 2010 Credit
Facility and the 2.75% Convertible Senior Notes (the 2.75% Notes), a corresponding event of
default would result under the 6.5% Notes.
A covenant in the indenture for the 6.5% Notes prohibits the Company from incurring any
additional indebtedness if its consolidated leverage ratio exceeds 4.00 to 1.00. As of September
30, 2010, this covenant would not have precluded the Company from borrowing under the 2010 Credit
Facility.
On March 10, 2010, the Company entered into Consent Agreements (the Consent Agreements) with
Highbridge International LLC, Whitebox Combined Partners, LP, Whitebox Convertible Arbitrage
Partners, LP, IAM Mini-Fund 14 Limited, HFR Combined Master Trust and Wolverine Convertible
Arbitrage Trading Limited (the Consenting Holders), who
collectively held a majority of the
$32,050 in aggregate principal amount outstanding of the 6.5% Notes. Pursuant to the Consent
Agreements, the Consenting Holders consented to modifications and amendments to the Indenture
substantially in the form and substance set forth in a third supplemental indenture (the Third
Supplemental Indenture) to the indenture for the 6.5% Notes. The Third Supplemental Indenture
initially provided, among other things, for an amendment to Section 6.13 of the Indenture so that
certain restrictions on the Companys ability to incur
indebtedness would not be applicable to the
borrowing by the Company of an amount not to exceed $300,000 under a new credit facility to be
entered into in connection with the acquisition of InfrastruX.
On May 10, 2010, the Company entered into an Amendment to Consent Agreement (the Amendment)
with the Consenting Holders. Pursuant to the Amendment, the Consenting Holders consented to
modifications to the Third Supplemental Indenture to clarify that certain restrictions on
the Companys ability to incur indebtedness would not be applicable to certain borrowings by the
Company to acquire InfrastruX regardless of whether the borrowing
consisted of a term loan under a
new credit agreement, a new series of notes or bonds or a combination thereof.
17
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
10. Long-term Debt (continued)
The Company is required to separately account for the debt and equity components of the 6.5%
Notes in a manner that reflects its nonconvertible debt borrowing rate at the time of issuance. The
difference between the fair value and the principal amount was recorded as a debt discount and as a
component of equity. The debt and equity components recognized for the Companys 6.5% Notes were
as follows:
|
|
|
|
|
|
|
|
|
|
|
September 30, |
|
|
December 31, |
|
|
|
2010 |
|
|
2009 |
|
Principal amount of 6.5% Notes |
|
$ |
32,050 |
|
|
$ |
32,050 |
|
Unamortized discount |
|
|
(155 |
) |
|
|
(600 |
) |
|
|
|
|
|
|
|
Net carrying amount |
|
$ |
31,895 |
|
|
$ |
31,450 |
|
|
|
|
|
|
|
|
Additional paid-in capital |
|
$ |
3,131 |
|
|
$ |
3,131 |
|
|
|
|
|
|
|
|
At September 30, 2010, the unamortized discount had a remaining recognition period of
approximately 3 months.
The amount of interest expense recognized and the effective interest rate for the three and
nine months ended September 30, 2010 and 2009 were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
Nine Months Ended |
|
|
|
September 30, |
|
|
September 30, |
|
|
|
2010 |
|
|
2009 |
|
|
2010 |
|
|
2009 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Contractual coupon interest |
|
$ |
521 |
|
|
$ |
521 |
|
|
$ |
1,562 |
|
|
$ |
1,562 |
|
Amortization of discount |
|
|
151 |
|
|
|
139 |
|
|
|
445 |
|
|
|
409 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense |
|
$ |
672 |
|
|
$ |
660 |
|
|
$ |
2,007 |
|
|
$ |
1,971 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effective interest rate |
|
|
8.46 |
% |
|
|
8.46 |
% |
|
|
8.46 |
% |
|
|
8.46 |
% |
2.75% Convertible Senior Notes
In 2004, the Company completed a primary offering of $60,000 of the 2.75% Notes. Also, in
2004, the initial purchasers of the 2.75% Notes exercised their option to purchase an additional
$10,000 aggregate principal amount of the 2.75% Notes. The primary offering and purchase option of
the 2.75% Notes totaled $70,000. The 2.75% Notes are general senior unsecured obligations. Interest
is paid semi-annually on March 15 and September 15. The 2.75% Notes mature on March 15, 2024 unless
the notes are repurchased, redeemed or converted earlier. Upon maturity, the principal amount plus
the accrued interest through the day prior to the maturity date is payable only in cash. The
indenture for the 2.75% Notes originally provided that the Company could redeem the 2.75% Notes for
cash on or after March 15, 2011, at 100 percent of the principal amount of the notes plus accrued
interest. An indenture amendment, as described more fully below, delayed the redemption date two
years to March 15, 2013. The holders of the 2.75% Notes have the right to require the Company to
purchase the 2.75% Notes, including unpaid interest, on March 15, 2011, 2014, and 2019 or upon a
change of control related event. On March 15, 2014 and 2019, the Company has the option of
providing its common stock in lieu of cash, or a combination of common stock and cash to fund
purchases. Based on the uncertainty surrounding the future economic conditions, the Company is
unable to estimate the probability of future repurchases of the 2.75% Notes on March 15, 2011.
Accordingly, all $58,006 (net of $1,351 bond discount) has been classified as short-term and
included within Notes payable and current portion of other long-term debt on the Consolidated
Balance Sheet at September 30, 2010.
Accrued interest on the notes on all three put dates can only be paid in cash. Upon the
occurrence of a fundamental change, as defined by the Indenture, the holders of the 2.75% Notes
have the right to require the Company to purchase the 2.75% Notes for cash, in addition to a
make-whole premium that is payable in cash or in additional shares of common stock. The holders
of the 2.75% Notes may, under certain circumstances, convert the notes into shares of the Companys
common stock at an initial conversion ratio of 51.3611 shares of common stock per $1,000.00
principal amount of notes representing a conversion price of approximately $19.47 per share and
resulting in 3,048,641 shares at September 30, 2010 based on the principal amount of the 2.75%
Notes which remain outstanding, subject to adjustment in certain circumstances. The notes will be
convertible only upon the occurrence of certain specified events including, but not limited to, if,
at certain times, the closing sale price of the Companys common stock exceeds 120.0 percent of the
then current conversion price, or $23.36 per share, based on the initial conversion price. In the
event of a default under any Company credit agreement other than the indenture covering the 2.75%
Notes, (1) in which the Company fails to pay principal or interest on
indebtedness with an aggregate principal balance of $10,000 or more; or (2) in which indebtedness
with a principal balance of $10,000 or more is accelerated, an event of default would result under
the 2.75% Notes.
18
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
10. Long-term Debt (continued)
An indenture amendment extended the initial date on or after which the 2.75% Notes may be
redeemed by the Company to March 15, 2013 from March 15, 2011 for cash at 100 percent of the
principal amount of the notes plus accrued interest. In addition, a new provision was added to the
indenture which requires the Company, in the event of a fundamental change which is a change of
control event in which 10.0 percent or more of the consideration in the transaction consists of
cash to make a coupon make-whole payment equal to the present value (discounted at the U.S.
treasury rate) of the lesser of (a) two years of scheduled payments of interest on the 2.75% Notes
or (b) all scheduled interest on the 2.75% Notes from the date of the transaction through March 15,
2013.
The Company is required to separately account for the debt and equity components of the 2.75%
Notes in a manner that reflects its nonconvertible debt borrowing rate at the time of issuance. The
difference between the fair value and the principal amount was recorded as a debt discount and as a
component of equity. The debt and equity components recognized for the Companys 2.75% Notes were
as follows:
|
|
|
|
|
|
|
|
|
|
|
September 30, |
|
|
December 31, |
|
|
|
2010 |
|
|
2009 |
|
Principal amount of 2.75% Notes |
|
$ |
59,357 |
|
|
$ |
59,357 |
|
Unamortized discount |
|
|
(1,351 |
) |
|
|
(3,286 |
) |
|
|
|
|
|
|
|
Net carrying amount |
|
$ |
58,006 |
|
|
$ |
56,071 |
|
|
|
|
|
|
|
|
Additional paid-in capital |
|
$ |
14,235 |
|
|
$ |
14,235 |
|
|
|
|
|
|
|
|
At September 30, 2010, the unamortized discount had a remaining recognition period of
approximately 6 months.
The amount of interest expense recognized and the effective interest rate for the three and
nine months ended September 30, 2010 and 2009 were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
Nine Months Ended |
|
|
|
September 30, |
|
|
September 30, |
|
|
|
2010 |
|
|
2009 |
|
|
2010 |
|
|
2009 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Contractual coupon interest |
|
$ |
408 |
|
|
$ |
408 |
|
|
$ |
1,224 |
|
|
$ |
1,224 |
|
Amortization of discount |
|
|
657 |
|
|
|
610 |
|
|
|
1,935 |
|
|
|
1,797 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense |
|
$ |
1,065 |
|
|
$ |
1,018 |
|
|
$ |
3,159 |
|
|
$ |
3,021 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effective interest rate |
|
|
7.40 |
% |
|
|
7.40 |
% |
|
|
7.40 |
% |
|
|
7.40 |
% |
Capital Leases
The Company has entered into multiple capital lease agreements to acquire various units of
construction equipment which have a weighted average 5.9 percent interest rate. Assets held under
capital leases at September 30, 2010 and December 31, 2009 are summarized below:
|
|
|
|
|
|
|
|
|
|
|
September 30, |
|
|
December 31, |
|
|
|
2010 |
|
|
2009 |
|
|
|
|
|
|
|
|
|
|
Construction equipment |
|
$ |
19,002 |
|
|
$ |
23,475 |
|
Auto, trucks and trailers |
|
|
6,739 |
|
|
|
1,895 |
|
Furniture and equipment |
|
|
1,881 |
|
|
|
1,911 |
|
|
|
|
|
|
|
|
Total assets held under capital lease |
|
|
27,622 |
|
|
|
27,281 |
|
Less: accumulated depreciation |
|
|
(7,992 |
) |
|
|
(9,800 |
) |
|
|
|
|
|
|
|
Net assets under capital lease |
|
$ |
19,630 |
|
|
$ |
17,481 |
|
|
|
|
|
|
|
|
19
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
10. Long-term Debt (continued)
The following are the minimum lease payments for assets financed under capital lease
arrangements as of September, 2010:
|
|
|
|
|
Fiscal year: |
|
|
|
|
2010 |
|
$ |
4,061 |
|
2011 |
|
|
5,487 |
|
2012 |
|
|
6,438 |
|
2013 |
|
|
1,073 |
|
2014 |
|
|
49 |
|
Thereafter |
|
|
|
|
|
|
|
|
Total minimum lease payments under capital lease obligations |
|
|
17,108 |
|
Less: future interest expense |
|
|
(1,133 |
) |
|
|
|
|
Net minimum lease payments under capital leases obligations |
|
|
15,975 |
|
Less: current portion of net minimum lease payments |
|
|
(7,248 |
) |
|
|
|
|
Long-term net minimum lease payments |
|
$ |
8,727 |
|
|
|
|
|
11. Retirement Benefits
The Company has defined contribution plans that are funded by participating employee
contributions and the Company. The Company matches employee contributions, up to a maximum of four
percent of salary, in the form of cash. The Company match was suspended in May 2009 through
December 2009 for all U.S. based plans and was reinstated in January 2010. Company contributions
for the plans were $2,458 and $1,372 as of September 30, 2010 and 2009, respectively.
In connection with the Companys acquisition of InfrastruX, the Company is subject to
additional collective bargaining agreements with various unions. As a result, the Company
participates with other companies in the unions multi-employer pension and other postretirement
benefit plans. These plans cover all employees who are members of such unions. The Employee
Retirement Income Security Act of 1974, as amended by the Multi-Employer Pension Plan Amendments
Act of 1980, imposes certain liabilities upon employers who are contributors to a multi-employer
plan in the event of the employers withdrawal from, or upon termination of, such plan. The Company
has no intention to withdraw from these plans. The plans do not maintain information on the net
assets and actuarial present value of the plans unfunded vested benefits allocable to the Company,
and the amounts, if any, for which the Company may be contingently liable, are not ascertainable at
this time. Contributions to all union multi-employer pension and other postretirement plans by the
Company were $13,147 and $5,340 as of September 30, 2010 and 2009.
12. Income Taxes
For the three months ended September 30, 2010, the Company recorded income tax expense based
on actual results rather than using a projected effective tax rate for the year. This was due in
part to contingent events occurring in the third quarter of 2010, such as deal costs incurred in
connection with the acquisition of InfrastruX, release of contingent earnout liability, goodwill
impairment and the vesting of stock based compensation that had a significant impact on income tax
expense.
In the third quarter of 2010, the total income tax benefit of $2,687 includes a $299 write-off
of deferred tax assets related to tax benefits previously recorded under Accounting Standard
Codification (ASC) 718 Stock Compensation that will no longer be realized and $3,453 of deal
costs that received no tax benefit. There was no tax expense required to be recorded in connection
with the $45,340 release of the contingent earnout liability.
13. Stockholders Equity
The information contained in this note pertains to continuing and discontinued operations.
Stock Ownership Plans
During May 1996, the Company established the Willbros Group, Inc. 1996 Stock Plan (the 1996
Plan) with 1,125,000 shares of common stock authorized for issuance to provide for awards to key
employees of the
Company, and the Willbros Group, Inc. Director Stock Plan (the Director Plan) with 125,000 shares
of common stock authorized for issuance to provide for the grant of stock options to non-employee
directors. The number of
shares authorized for issuance under the 1996 Plan and the Director Plan was increased to 4,825,000
and 225,000, respectively, by stockholder approval. The Director Plan expired August 16, 2006. In
2006, the Company established the 2006 Director Restricted Stock Plan (the 2006 Director Plan)
with 50,000 shares authorized for issuance to grant shares of restricted stock and restricted stock
rights to non-employee directors.
20
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
13. Stockholders Equity (continued)
The number of shares authorized for issuance under the 2006 Director Plan was increased in
2008 to 250,000 by stockholder approval.
On May 26, 2010, the Company established the Willbros Group, Inc. 2010 Stock and Incentive
Compensation Plan (2010 Plan) with 2,100,000 shares of common stock authorized for issuance to
provide for awards to key employees of the Company. All future grants of stock awards to key
employees will be made through the 2010 Plan. On May 26, 2010, the 1996 Plan was frozen, with the
exception of normal vesting, forfeiture and other activity associated with awards previously
granted under the 1996 Plan. At September 30, 2010, the 2010 plan had 1,968,392 shares available
for grant.
Restricted stock and restricted stock rights, also described collectively as restricted stock
units (RSUs) and options granted to employees vest generally over a three to four year period.
Options granted under the Director Plan are fully vested. Restricted stock and restricted stock
rights granted under the 2006 Director Plan vest one year after the date of grant. At September 30,
2010, the 2006 Director Plan had 121,711 shares available for
grant. Certain provisions allow for accelerated vesting based on increases of share prices and on
eligible retirement. Compensation expense of $504 and $2,072, for the nine months ended September
30, 2010 and 2009, respectively, and $223 and $39, for the three months ended September 30, 2010
and 2009, respectively, was recognized due to accelerated vesting of RSUs due to retirements and
separation from the Company.
Share-based compensation related to RSUs is recorded based on the Companys stock price as of
the grant date. Expense from both stock options and RSUs totaled $1,911 and $2,371, for the three
months ended September 30, 2010 and 2009, respectively, and $6,489 and $9,321, for the nine months
ended September 30, 2010 and 2009, respectively.
The Company determines the fair value of stock options as of its grant date using the
Black-Scholes valuation method. No options were granted during the three or nine months ended
September 30, 2010 and 2009. Stock option activity for the nine months ended September 30, 2010
consists of:
|
|
|
|
|
|
|
|
|
|
|
Number of |
|
|
Weighted Average |
|
|
|
Options |
|
|
Exercise Price |
|
|
|
|
|
|
|
|
|
|
Outstanding at January 1, 2010 |
|
|
257,750 |
|
|
$ |
15.91 |
|
Granted |
|
|
|
|
|
|
|
|
Exercised |
|
|
|
|
|
|
|
|
Forfeited, expired and other |
|
|
(30,000 |
) |
|
|
20.65 |
|
|
|
|
|
|
|
|
Outstanding at September 30, 2010 |
|
|
227,750 |
|
|
$ |
15.28 |
|
|
|
|
|
|
|
|
Exercisable at September 30, 2010 |
|
|
195,250 |
|
|
$ |
14.84 |
|
|
|
|
|
|
|
|
As of September 30, 2010, the aggregate intrinsic value of stock options outstanding and stock
options exercisable was $96 and $96, respectively. The weighted average remaining contractual term
of outstanding options is 4.54 years and the weighted average remaining contractual term of the
exercisable options is 4.37 years at September 30, 2010. The total intrinsic value of options
exercised during the nine months ended September 30, 2010 and 2009 was $0 and $71, respectively.
The total fair value of options vested during the three and nine months ended September 30,
2010 and 2009 was $0 and $0, respectively.
21
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
13. Stockholders Equity (continued)
The Companys non-vested options at September 30, 2010 and the changes in non-vested options
during the nine months ended September 30, 2010 are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted |
|
|
|
|
|
|
|
Average Grant- |
|
|
|
Shares |
|
|
Date Fair Value |
|
|
|
|
|
|
|
|
|
|
Nonvested, January 1, 2010 |
|
|
37,500 |
|
|
$ |
7.23 |
|
Granted |
|
|
|
|
|
|
|
|
Vested |
|
|
|
|
|
|
|
|
Forfeited or expired |
|
|
(5,000 |
) |
|
|
9.69 |
|
|
|
|
|
|
|
|
Nonvested, September 30, 2010 |
|
|
32,500 |
|
|
$ |
6.85 |
|
|
|
|
|
|
|
|
The Companys RSU activity and related information for the nine months ended September 30,
2010 consists of:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted |
|
|
|
Number of |
|
|
Average Grant- |
|
|
|
RSUs |
|
|
Date Fair Value |
|
|
|
|
|
|
|
|
|
|
Outstanding at January 1, 2010 |
|
|
859,248 |
|
|
$ |
22.38 |
|
Granted |
|
|
549,849 |
|
|
|
11.83 |
|
Vested |
|
|
(325,644 |
) |
|
|
22.74 |
|
Forfeited |
|
|
(18,500 |
) |
|
|
22.21 |
|
|
|
|
|
|
|
|
Outstanding September 30, 2010 |
|
|
1,064,953 |
|
|
$ |
16.81 |
|
|
|
|
|
|
|
|
The total fair value of RSUs vested during the nine months ended September 30, 2010 and 2009
was $7,406 and $9,174, respectively.
As of September 30, 2010, there was a total of $9,933 of unrecognized compensation cost, net
of estimated forfeitures, related to all non-vested share-based compensation arrangements granted
under the Companys stock ownership plans. That cost is expected to be recognized over a
weighted-average period of 1.2 years.
Warrants to Purchase Common Stock
On October 27, 2006, the Company completed a private placement of equity to certain accredited
investors pursuant to which the Company issued and sold 3,722,360 shares of the Companys common
stock resulting in net proceeds of $48,748. In conjunction with the private placement, the Company
also issued warrants to purchase an additional 558,354 shares of the Companys common stock. Each
warrant is exercisable, in whole or in part, until 60 months from the date of issuance. A warrant
holder may elect to exercise the warrant by delivery of payment to the Company at the exercise
price of $19.03 per share, or pursuant to a cashless exercise as provided in the warrant agreement.
The fair value of the warrants was $3,423 on the date of the grant, as calculated using the
Black-Scholes option-pricing model. There were 536,925 warrants outstanding at September 30, 2010
and 2009, respectively.
14. Income (Loss) Per Share
Basic income (loss) per share is computed by dividing net income (loss) by the weighted
average number of common shares outstanding for the period. Diluted income (loss) per share is
based on the weighted average number of shares outstanding during each period and the assumed
exercise of potentially dilutive stock options and warrants and vesting of restricted stock and
restricted stock rights less the number of treasury shares assumed to be purchased from the
proceeds using the average market price of the Companys stock for each of the periods presented.
The Companys convertible notes are included in the calculation of diluted income per share under
the if-converted method. Additionally, diluted income per share for continuing operations is
calculated excluding the after-tax interest expense associated with the convertible notes since
these notes are treated as if converted into common stock.
22
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
14. Income (Loss) Per Share (continued)
Basic and diluted income (loss) from continuing operations per common share for the three and
nine months ended September 30, 2010 and 2009 are computed as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months |
|
|
Nine Months |
|
|
|
Ended September 30, |
|
|
Ended September 30, |
|
|
|
2010 |
|
|
2009 |
|
|
2010 |
|
|
2009 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations |
|
$ |
36,279 |
|
|
$ |
2,055 |
|
|
$ |
32,959 |
|
|
$ |
29,121 |
|
Less: Income attributable
to noncontrolling interest |
|
|
(293 |
) |
|
|
(372 |
) |
|
|
(902 |
) |
|
|
(1,543 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income from continuing
operations attributable to
Willbros Group, Inc.
(numerator for basic
calculation) |
|
|
35,986 |
|
|
|
1,683 |
|
|
|
32,057 |
|
|
|
27,578 |
|
Add: Interest and debt
issuance costs associated
with convertible notes |
|
|
1,246 |
|
|
|
|
|
|
|
2,108 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income from continuing
operations applicable to
common shares (numerator
for diluted calculation) |
|
$ |
37,232 |
|
|
$ |
1,683 |
|
|
$ |
34,165 |
|
|
$ |
27,578 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average number of
common shares outstanding
for basic income per share |
|
|
46,997,431 |
|
|
|
38,721,586 |
|
|
|
41,651,994 |
|
|
|
38,656,656 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average number of
potentially dilutive common
shares outstanding |
|
|
5,156,598 |
|
|
|
197,347 |
|
|
|
3,238,011 |
|
|
|
160,755 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average number of
common shares outstanding
for diluted income per
share |
|
|
52,154,029 |
|
|
|
38,918,933 |
|
|
|
44,890,005 |
|
|
|
38,817,411 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income per common share from
continuing operations: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic |
|
$ |
0.77 |
|
|
$ |
0.04 |
|
|
$ |
0.77 |
|
|
$ |
0.71 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted |
|
$ |
0.71 |
|
|
$ |
0.04 |
|
|
$ |
0.76 |
|
|
$ |
0.71 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The Company has excluded shares potentially issuable under the terms of use of the securities
listed below from the computation of diluted income (loss) per share, as the effect would be
anti-dilutive:
|
|
|
|
|
|
|
|
|
|
|
Three Months |
|
|
|
Ended September 30, |
|
|
|
2010 |
|
|
2009 |
|
|
|
|
|
|
|
|
|
|
2.75% Convertible Senior Notes |
|
|
|
|
|
|
3,048,641 |
|
6.5% Senior Convertible Notes |
|
|
|
|
|
|
1,825,587 |
|
Stock options |
|
|
187,860 |
|
|
|
207,750 |
|
Warrants to purchase common stock |
|
|
536,925 |
|
|
|
536,925 |
|
|
|
|
|
|
|
|
|
|
|
724,785 |
|
|
|
5,618,903 |
|
|
|
|
|
|
|
|
In accordance with the FASBs standard on earnings per share contingently convertible
instruments, the shares issuable upon conversion of the convertible notes are considered to be
dilutive regardless of whether the Companys stock price was greater than or equal to the
conversion prices of $17.56 and $19.47. However, these securities are only dilutive to the extent
that interest per weighted average convertible share does not exceed basic earnings per share.
For the three months ended September 30, 2010, the
related interest per convertible share associated with the 2.75% Convertible Senior Notes and the
6.5% Senior Convertible Note did not exceed basic earnings per share
for the current period.
As such, those
shares have been included in the computation of diluted earnings per share.
23
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
15. Segment Information
The Companys segments are strategic business units that are defined by the industry segments
served and are managed separately as each has different operational requirements and strategies.
Prior to the InfrastruX acquisition, the Company operated through two business segments: Upstream
Oil & Gas and Downstream Oil & Gas. These segments operate primarily in the United States, Canada,
and Oman. On July 1, 2010, the Company closed on the acquisition of InfrastruX. InfrastruX is a
provider of electric power and natural gas transmission and distribution maintenance and
construction solutions to customers from their regional operating centers in the South Central,
Midwest and East Coast regions of the United States. This acquisition significantly diversifies the
Companys capabilities and end markets. InfrastruX has been designated as a newly established
segment: Utility T&D. Management evaluates the performance of each operating segment based on
operating income. Corporate operations include the executive management, general, administrative,
and financing functions of the organization. The costs to provide these services are allocated, as
are certain other corporate assets, among the three operating segments. There were no material
inter-segment revenues in the periods presented.
At the beginning of the third quarter of 2009, the Company acquired the engineering business
of Wink Companies, LLC (Wink). In anticipation of this acquisition, in the second quarter of
2009, the Company redefined its business segments from Engineering, Upstream Oil & Gas and
Downstream Oil & Gas to two segments by integrating the existing Engineering segment into the
Upstream Oil & Gas segment and Wink into the Downstream Oil & Gas segment. The Company believes
the inclusion of engineering services within each segment improves internal connectivity by
providing dedicated, specialized engineering services to both the upstream and downstream markets.
Additionally, in the third quarter of 2009, the Companys compressor/pump station construction
business that was previously included in the Downstream Oil & Gas segment was moved to the Upstream
Oil & Gas segment. The financial results for this business have been reclassified for all periods
presented here into the Upstream Oil & Gas segment.
The following tables reflect the Companys reconciliation of segment operating results to net
income (loss) in the Condensed Consolidated Statements of Income for the three and nine months
ended September 30, 2010 and 2009:
For the three months ended September 30, 2010:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Upstream |
|
|
Downstream |
|
|
|
|
|
|
|
|
|
Oil & Gas |
|
|
Oil & Gas |
|
|
Utility T&D |
|
|
Consolidated |
|
Revenue |
|
$ |
169,749 |
|
|
$ |
80,870 |
|
|
$ |
158,173 |
|
|
$ |
408,792 |
|
Operating expenses |
|
|
142,769 |
|
|
|
80,476 |
|
|
|
174,190 |
|
|
|
397,435 |
|
Goodwill impairment |
|
|
|
|
|
|
12,000 |
|
|
|
|
|
|
|
12,000 |
|
Changes in fair value of contingent earnout liability |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(45,340 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income (loss) |
|
$ |
26,980 |
|
|
$ |
(11,606 |
) |
|
$ |
(16,017 |
) |
|
|
44,697 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other expense |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(11,105 |
) |
Benefit from income taxes |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(2,687 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
36,279 |
|
Loss from discontinued operations net of provision
for income taxes |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(578 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing and discontinued operations |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
35,701 |
|
Less: Income attributable to noncontrolling interest |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(293 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income attributable to Willbros Group, Inc. |
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
35,408 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
24
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
15. Segment Information (continued)
For the three months ended September 30, 2009:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Upstream |
|
|
Downstream |
|
|
|
|
|
|
|
|
|
Oil & Gas |
|
|
Oil & Gas |
|
|
Utility T&D |
|
|
Consolidated |
|
Revenue |
|
$ |
190,172 |
|
|
$ |
57,361 |
|
|
|
N/A |
|
|
$ |
247,533 |
|
Operating expenses |
|
|
184,712 |
|
|
|
59,322 |
|
|
|
N/A |
|
|
|
244,034 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income (loss) |
|
$ |
5,460 |
|
|
$ |
(1,961 |
) |
|
|
N/A |
|
|
|
3,499 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other expense |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(2,103 |
) |
Benefit from income taxes |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(659 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,055 |
|
Loss from discontinued operations net of provision
for income taxes |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(27 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing and discontinued operations |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,028 |
|
Less: Income attributable to noncontrolling interest |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(372 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income attributable to Willbros Group, Inc. |
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
1,656 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the nine months ended September 30, 2010:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Upstream |
|
|
Downstream |
|
|
|
|
|
|
|
|
|
Oil & Gas |
|
|
Oil & Gas |
|
|
Utility T&D |
|
|
Consolidated |
|
Revenue |
|
$ |
432,849 |
|
|
$ |
202,895 |
|
|
$ |
158,173 |
|
|
$ |
793,917 |
|
Operating expenses |
|
|
394,900 |
|
|
|
217,857 |
|
|
|
174,190 |
|
|
|
786,947 |
|
Goodwill impairment |
|
|
|
|
|
|
12,000 |
|
|
|
|
|
|
|
12,000 |
|
Changes in fair value of contingent earnout liability |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(45,340 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income (loss) |
|
$ |
37,949 |
|
|
$ |
(26,962 |
) |
|
$ |
(16,017 |
) |
|
|
40,310 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other expense |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(12,425 |
) |
Benefit from income taxes |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(5,074 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
32,959 |
|
Loss from discontinued operations net of provision
for income taxes |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,324 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing and discontinued operations |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
31,635 |
|
Less: Income attributable to noncontrolling interest |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(902 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income attributable to Willbros Group, Inc. |
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
30,733 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the nine months ended September 30, 2009:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Upstream |
|
|
Downstream Oil |
|
|
|
|
|
|
|
|
|
Oil & Gas |
|
|
& Gas |
|
|
Utility T&D |
|
|
Consolidated |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenue |
|
$ |
854,066 |
|
|
$ |
211,875 |
|
|
|
N/A |
|
|
$ |
1,065,941 |
|
Operating expenses |
|
|
807,086 |
|
|
|
210,366 |
|
|
|
N/A |
|
|
|
1,017,452 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income (loss) |
|
$ |
46,980 |
|
|
$ |
1,509 |
|
|
|
N/A |
|
|
|
48,489 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other expense |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(6,111 |
) |
Provision for income taxes |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
13,257 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
29,121 |
|
Loss from discontinued operations
net of provision for income taxes |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,527 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing and
discontinued operations |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
27,594 |
|
Less: Income attributable to
noncontrolling interest |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,543 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income attributable to
Willbros Group, Inc. |
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
26,051 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
25
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
15. Segment Information (continued)
Total assets by segment as of September 30, 2010 and December 31, 2009 are presented below:
|
|
|
|
|
|
|
|
|
|
|
September 30, |
|
|
December 31, |
|
|
|
2010 |
|
|
2009 |
|
Upstream Oil & Gas |
|
$ |
292,154 |
|
|
$ |
259,038 |
|
Downstream Oil & Gas |
|
|
180,662 |
|
|
|
174,512 |
|
Utility T&D |
|
|
706,285 |
|
|
|
|
|
Corporate |
|
|
163,052 |
|
|
|
294,828 |
|
|
|
|
|
|
|
|
Total assets, continuing operations |
|
$ |
1,342,153 |
|
|
$ |
728,378 |
|
|
|
|
|
|
|
|
16. Contingencies, Commitments and Other Circumstances
Contingencies
Resolution of criminal and regulatory matters
In May 2008, the United States Department of Justice filed an Information and Deferred
Prosecution Agreement (DPA) in the United States District Court in Houston concluding its
investigation into violations of the Foreign Corrupt Practices Act of 1977, as amended, by Willbros
Group, Inc. and its subsidiary Willbros International, Inc. (WII). Also in May 2008, WGI reached
a final settlement with the SEC to resolve its previously disclosed investigation of possible
violations of the FCPA and possible violations of the Securities Act of 1933 and the Securities
Exchange Act of 1934. These investigations stemmed primarily from the Companys former operations
in Bolivia, Ecuador and Nigeria. The settlements together require the Company to pay, over
approximately three years, a total of $32,300 in penalties and disgorgement, plus post-judgment
interest on $7,725 of that amount. As part of its agreement with the SEC, the Company will be
subject to a permanent injunction barring future violations of certain provisions of the federal
securities laws. As to its agreement with the DOJ, both WGI and WII for a period of three years
from May 2008, are subject to the DPA, which among its terms provides that, in exchange for WGIs
and WIIs full compliance with the DPA, the DOJ will not continue a criminal prosecution of WGI and
WII and with the successful completion of the DPAs terms, the DOJ will move to dismiss the
criminal information.
For the term of the DPA, WGI and WII will fully cooperate with the government and comply with
all federal criminal laws including but not limited to the FCPA. As provided for in the DPA,
with the approval of the DOJ and effective September 25, 2009, the Company retained a government
approved independent monitor, at the Companys expense, for a two and one-half year period, who is
reporting to the DOJ on the Companys compliance with the DPA.
Since the appointment of the monitor, the Company has cooperated and provided the monitor with
access to information, documents, records, facilities and employees. On March 1, 2010, the monitor
filed with the DOJ the first of three required reports under the DPA. In the report, the monitor
made numerous findings and recommendations to the Company with respect to the improvement of its
internal controls, policies and procedures for detecting and preventing violations of applicable
anti-corruption laws.
The Company is obligated, pursuant to the terms of the DPA, to adopt the recommendations in
the monitors report unless the Company advises the monitor and the DOJ that it considers the
recommendations unduly burdensome, impractical, costly or otherwise inadvisable. The Company has
advised the DOJ that it intends to implement all of the recommendations. The Company will require
increased resources, costs and management oversight in order to effectively implement the
recommendations.
Failure by the Company to comply with the terms and conditions of either settlement could
result in resumed prosecution and other regulatory sanctions.
Facility Construction Project Termination
In September 2008, TransCanada Pipelines, Ltd. (TCPL) awarded the Company the cost
reimbursable plus fixed fee construction contract for seven pump stations in Nebraska and Kansas.
On January 13, 2010, TCPL notified the Company that it was in breach of the contract and was being
terminated for cause immediately. At the time of termination, the Company had completed
approximately 91.0 percent of its scope of work.
26
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
16. Contingencies, Commitments and Other Circumstances (continued)
The Company has disputed the validity of the termination for cause and has challenged the
contractual procedure followed by TCPL for termination for cause, which allows for a 30 day
notification period during which time the Company is granted the opportunity to remedy the alleged
default. Despite not being granted this time, the Company agreed in good faith to cooperate with
TCPL in an orderly demobilization and handover of the remaining work. As of September 30, 2010, the
Company has outstanding receivables related to this project of $71,159 and unapproved change orders
for additional work of $3,655 which has not been billed. Additionally, there are claims for
additional fees totaling $16,714. It is the Companys policy not to recognize revenue or income on
unapproved change orders or claims until they have been approved. Accordingly, the $3,655 in
pending change orders and the $16,714 of claims have been excluded from the Companys revenue
recognition.
If the termination for cause is determined to be valid and enforceable, the Company could be
held liable for any damages resulting from the alleged breach of contract, including but not
limited to costs incurred by TCPL to hire a replacement contractor to complete the estimated 9%
remainder of the work less the cost that the Company would have incurred to perform the same scope
of work.
In May and June of 2010, the Company filed liens on the constructed facilities. On June 16,
2010 the Company notified TCPL that the Company intended to exercise its rights to conflict
resolution under the contract, and on July 6, 2010, the International Chamber of Commerce received
the Companys request for arbitration. On September 15, 2010, the Company received TCPLs response
to the Notice of Arbitration, which included a counterclaim for damages of $23,000 for the alleged
breach of contract. In addition, TCPL has disclaimed its responsibility for payment of the current
receivable balance outstanding as of September 30, 2010, the unapproved change orders for
additional work, and claims for additional fees.
At this point the Company cannot estimate the probable outcome of the arbitration, but the
Company believes it is not in breach of contract and will defend its contractual rights. No
allowance for collection has been established for the $71,159 of outstanding accounts receivable.
The length of the arbitration process cannot be estimated at this time.
TransCanada has removed the Company from TransCanadas bid list.
Pipeline Construction Project Issues
In July 2007, the Company announced the award of an installation contract (42-inch Contract)
for the construction of three segments of the Midcontinent Express Pipeline Project (MEP Project)
by Midcontinent Express Pipeline LLC (MEP). The contract is structured as a cost reimbursable
contract with a fixed fee for the Company. In September 2008, the Company and MEP signed an
amendment which finalized the scope of work under the 42-inch Contract as the construction of 179
miles of 42-inch pipeline. The amendment also included the award to the Company of an additional
installation contract (36-inch Contract) for the construction of 136 miles of 36-inch pipeline
which at the time was anticipated to start in March 2009.
In its Form 10-K for the year ended December 31, 2008, the Company referenced an ongoing
dispute between MEP and the Company in which a portion of the scope of work on the 42-inch Contract
was terminated for cause and the 36-inch Contract was terminated for convenience. This issue has
subsequently been resolved and MEP has paid a termination fee for the cancellation of the 36-inch
Contract. The payment was received by the Company in the first quarter of 2009.
Furthermore, the Company achieved mechanical completion of the 179 miles on the 42-inch
pipeline in April 2009 and completed close out efforts in the first quarter of 2010.
Project claims and audit disputes
Post-contract completion audits and reviews are periodically conducted by clients and/or
government entities on certain contracts. As of September 30, 2010, the Company has been notified
of claims and audit assertions totaling $16,929. The claims are associated with a single gross
maximum price contract. In accordance with the agreements, the Company has continued billing costs
beyond the gross maximum price. Any unresolved claims and audit exceptions are first applied
against any excess billings. Currently, the Company has excess billings of $12,210. It is the
Companys position that the excess billings are sufficient to cover the assessed risks associated
with all outstanding claims. The Company is actively engaged to resolve these disputes. There can
be no assurance as to the resolution of these claims and assertions.
27
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
16. Contingencies, Commitments and Other Circumstances (continued)
Legal Proceedings
In addition to the matters discussed above, the Company is party to a number of legal
proceedings. Management believes that the nature and number of these proceedings are typical for a
firm of similar size engaged in a similar type of business and that none of these proceedings is
material to the Companys financial position. See Note 19 Discontinuance of Operations, Asset
Disposals, and Transition Services Agreement for additional information pertaining to legal
proceedings.
Pre-acquisition contingencies
The Company has evaluated and continues to evaluate contingencies relating to the acquisition
of InfrastruX that existed as of the acquisition date. The Company has preliminarily determined
that certain of these pre-acquisition contingencies are probable in nature and estimable as of the
acquisition date and, accordingly, has recorded the best estimates for these contingencies as a
part of the purchase price allocation for InfrastruX. The Company continues to gather information
for and evaluate substantially all pre-acquisition contingencies that it has assumed from
InfrastruX. If the Company makes changes to the amounts recorded or identifies additional
pre-acquisition contingencies during the remainder of the measurement period, such amounts recorded
will be included in the purchase price allocation during the measurement period and, subsequently,
in the results of operations.
Commitments
From time to time, the Company enters into commercial commitments, usually in the form of
commercial and standby letters of credit, surety bonds and financial guarantees. Contracts with the
Companys customers may require the Company to secure letters of credit or surety bonds with regard
to the Companys performance of contracted services. In such cases, the commitments can be called
upon in the event of failure to perform contracted services. Likewise, contracts may include
contract retention provisions, in which case the client withholds a percentage of the contract
value until project completion or expiration of a warranty period. Retention commitments can be
called upon in the event of warranty or project completion issues, as prescribed in the contracts.
At September 30, 2010, the Company had approximately $9,689 of letters of credit outstanding, all
related to continuing operations. Additionally, the Company had $456,306 of primary surety bonds
outstanding related to continuing operations. These amounts represent the maximum amount of future
payments the Company could be required to make if the letters of credit are drawn upon and claims
are made under the surety bonds. As of September 30, 2010, no liability has been recognized for
letters of credit and surety bonds.
Other Circumstances
Operations outside the United States may be subject to certain risks, which ordinarily would
not be expected to exist in the United States, including foreign currency restrictions, extreme
exchange rate fluctuations, expropriation of assets, civil uprisings and riots, war, unanticipated
taxes including income taxes, excise duties, import taxes, export taxes, sales taxes or other
governmental assessments, availability of suitable personnel and equipment, termination of existing
contracts and leases, government instability and legal systems of decrees, laws, regulations,
interpretations and court decisions which are not always fully developed and which may be
retroactively applied. Management is not presently aware of any events of the type described in the
countries in which it operates that would have a material effect on the financial statements, and
no such events have been provided for in the accompanying condensed consolidated financial
statements.
Based upon the advice of local advisors in the various work countries concerning the
interpretation of the laws, practices and customs of the countries in which the Company operates,
management believes the Company follows the current practices in those countries and as applicable
under the FCPA. However, because of the nature of these potential risks, there can be no assurance
that the Company may not be adversely affected by them in the future.
The Company insures substantially all of its equipment in countries outside the United States
against certain political risks and terrorism through political risk insurance coverage that
contains a 20.0 percent co-insurance provision. The Company has the usual liability of contractors
for the completion of contracts and the warranty of its work. Where work is performed through a
joint venture, the Company also has possible liability for the contract completion and warranty
responsibilities of its joint venture partners. In addition, the Company acts as prime contractor
on a majority of the projects it undertakes and is normally responsible for the performance of the
entire project, including subcontract work. Management is not aware of any material exposure
related thereto which has not been provided for in the accompanying condensed consolidated
financial statements.
28
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
16. Contingencies, Commitments and Other Circumstances (continued)
The Company attempts to manage contract risk by implementing a standard contracting philosophy
to minimize liabilities assumed in the agreements with the Companys clients. With the acquisitions
the Company has made in the last few years, however, there may be contracts or master service
agreements in place that do not meet the Companys current contracting standards. While the Company
has made efforts to improve its contractual terms with its clients, this process takes time to
implement. The Company has attempted to mitigate the risk by requesting amendments with its clients
and by maintaining primary and excess insurance, of certain specified limits, in the event a loss
was to ensue.
17. Fair Value Measurements
ASC 820 defines fair value as the price that would be received from selling an asset or paid
to transfer a liability in an orderly transaction between market participants at the measurement
date. When determining the fair value measurements for assets and liabilities required or permitted
to be recorded at fair value, the Company considers the principal or most advantageous market in
which it would transact and considers assumptions that market participants would use when pricing
the asset or liability, such as inherent risk, transfer restrictions, and risk of nonperformance.
Fair Value Hierarchy
ASC 820 establishes a fair value hierarchy that requires an entity to maximize the use of
observable inputs and minimize the use of unobservable inputs when measuring fair value. A
financial instruments categorization within the fair value hierarchy is based upon the lowest
level of input that is significant to the fair value measurement. ASC 820 establishes three levels
of inputs that may be used to measure fair value:
Level 1 Quoted prices in active markets for identical assets or liabilities.
Level 2 Observable inputs other than Level 1 prices such as quoted prices for similar assets or
liabilities.
Level 3 Unobservable inputs to the valuation methodology that are significant to the measurement
of fair value of assets or liabilities.
Assets and Liabilities Measured at Fair Value on a Recurring Basis
The Company measures its financial assets and financial liabilities, specifically its hedging
arrangements and contingent earnout liability, at fair value on a recurring basis. The fair value
of these financial assets and liabilities was determined using the following inputs as of September
30, 2010:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Quoted Prices in |
|
|
Significant |
|
|
Significant |
|
|
|
|
|
|
|
Active Markets for |
|
|
Other |
|
|
Other |
|
|
|
|
|
|
|
Identical Assets |
|
|
Observable |
|
|
Unobservable |
|
|
|
Total |
|
|
(Level 1) |
|
|
Inputs (Level 2) |
|
|
Inputs (Level 3) |
|
Assets: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest rate cap |
|
$ |
3 |
|
|
$ |
|
|
|
$ |
3 |
|
|
$ |
|
|
Liabilities: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Contingent earnout liability |
|
|
10,000 |
|
|
|
|
|
|
|
|
|
|
|
10,000 |
|
Interest rate swap |
|
|
711 |
|
|
|
|
|
|
|
711 |
|
|
|
|
|
Contingent earnout liability
In connection with the acquisition of InfrastruX on July 1, 2010, InfrastruX shareholders are
eligible to receive earnout payments of up to $125,000 if certain EBITDA targets are met. The
earnout payments begin when EBITDA, adjusted for certain items specifically identified within the
merger agreement, for the InfrastruX business equals or exceeds:
|
|
|
$175,000 for 2010 and 2011 combined (the Bonus Earnout Amount). |
29
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
17. Fair Value Measurements (continued)
If earned, the 2010 and 2011 earnout payments and the Bonus Earnout Amount will be paid to
former InfrastruX shareholders who qualify as accredited investors as defined by the SEC in a
combination of cash and non-convertible, non-voting preferred stock of the Company, pursuant to the
terms within the Merger, and to non-accredited former InfrastruX shareholders and former holders of
InfrastruX RSUs in the form of cash.
The Company estimated the fair value of the contingent earnout liability based on its
probability assessment of InfrastruXs EBITDA achievements during the earnout period. In developing
these estimates, the Company considered its revenue and EBITDA projections, its historical results,
and general macro-economic environment and industry trends. This fair value measurement is based on
significant revenue and EBITDA inputs not observed in the market and thus represents a Level 3
measurement. Level 3 instruments are valued based on unobservable inputs that are supported by
little or no market activity and reflect the Companys own assumptions in measuring fair value. The
Companys fair value estimate of this liability was $55,340. Changes in
the fair value of the contingent earnout liability subsequent to the acquisition date, including
changes arising from events that occurred after the acquisition date, such as changes in the
Companys estimate of revenue achievements, are recognized in earnings in the periods when the
estimated fair value changes.
The following table represents a reconciliation of the change in the fair value measurement of
the contingent earnout liability for the three months ended September 30, 2010 and 2009:
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
|
September 30, |
|
|
|
2010 |
|
|
2009 |
|
Beginning balance |
|
$ |
55,340 |
|
|
$ |
|
|
Change in fair value of contingent earnout
liability included in operating expenses |
|
|
(45,340 |
) |
|
|
|
|
|
|
|
|
|
|
|
Ending balance |
|
$ |
10,000 |
|
|
$ |
|
|
|
|
|
|
|
|
|
During the third quarter of 2010, the Company recorded a $45,340 adjustment to the estimated
fair value of the contingent earnout liability. This change in estimated contingent earnout
liability to the former InfrastruX shareholders was due to a third quarter decrease in the
probability-weighted estimated achievement of EBITDA targets as set forth in the merger agreement.
This reduction was driven primarily by the following:
|
|
|
Expectations for lower margins on major transmission projects due to (i) a shift in the
mix of projects in Texas towards lower margin projects than previously anticipated and (ii)
ongoing competition in other regions, particularly the northeast, as the pace of bid
activity has been slower than expected in returning to pre-2009 levels; |
|
|
|
A slower than anticipated rebound in key housing markets continues to pressure work
volumes under existing MSAs and the budgets of many of our utility customers, while
increasing the competitive pricing on bids for new awards; |
|
|
|
Reduced expectations for significant storm work, which typically carries a higher margin
than our standard MSA work. |
In accordance with ASC 805, Business Combinations, the Company reviews the contingent earnout
liability on a quarterly basis in order to determine its fair value. Changes in the fair value of
the liability are recorded within operating expenses in the period in which the change is made and
the liability may increase or decrease on a quarterly basis until the earnout period has concluded.
Hedging Arrangements
The Company attempts to negotiate contracts that provide for payment in U.S. dollars, but it
may be required to take all or a portion of payment under a contract in another currency. To
mitigate non-U.S. currency exchange risk, the Company seeks to match anticipated non-U.S. currency
revenue with expenses in the same currency whenever possible. To the extent it is unable to match
non-U.S. currency revenue with expenses in the same currency, the Company may use forward
contracts, options or other common hedging techniques in the same non-U.S. currencies. The Company
had no derivative financial instruments to hedge currency risk at September 30, 2010 or December
31, 2009.
Interest Rate Swap
In conjunction with the new credit agreement the Company entered into as of June 30, 2010, the
Company is subject to hedging arrangements to fix or otherwise limit the interest cost of the term
loans. The Company is subject to interest rate risk on its debt and investment of cash and cash
equivalents arising in the normal course of business, as the Company does not engage in speculative
trading strategies.
In
September 2010, the Company entered into two 18-month forward
interest rate swap agreements for a total notional
amount of $150,000 in order to hedge changes in the variable rate interest expense of half of the
$300,000 Term Loan maturing on June 30, 2014. Under the swap agreement, the Company
receives interest at a floating rate of three-month Libor, conditional on three-month Libor
exceeding 2 percent (to mirror variable rate interest provisions of the underlying hedged debt),
and pays interest at a fixed rate of 2.685 percent, effective March 28, 2012 through June 30, 2014.
The swap agreement is designated and qualifies as a cash flow hedging instrument, with the
effective portion of the swaps change in fair value recorded in
Other Comprehensive Income (OCI).
The swap of the variable rate interest is deemed to be a highly effective hedge, and resulted in no
gain or loss recorded for hedge ineffectiveness in the consolidated condensed statement of
income. Amounts in OCI are reported in interest expense when the hedged interest payments on
the underlying debt are recognized. The fair value of the swap agreement was determined using a
model with Level 2 inputs including quoted market prices for contracts with similar terms and
maturity dates.
30
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
17. Fair Value Measurements (continued)
Interest Rate Caps
In September 2010, the Company entered into two interest rate cap agreements for notional
amounts of $75,000 each in order to limit its exposure to an increase of the interest rate above 3
percent, effective September 28, 2010 through March 28, 2012. Total premiums of $98 were paid for
the interest rate caps. The cap agreements are designated and qualify as cash flow hedging
instruments, with the effective portion of the caps change in fair value recorded in OCI. Amounts
in OCI and the premiums paid for the caps are reported in interest expense as the hedged interest
payments on the underlying debt are recognized. The interest rate caps are deemed to be highly
effective, resulting in an immaterial amount of hedge ineffectiveness recorded in the consolidated
condensed statement of income. The fair value of the Interest Rate Cap Agreements was
determined using a model with Level 2 inputs including quoted market prices for contracts with
similar terms and maturity dates. An immaterial amount of OCI relating to the interest rate swap
and caps is expected to be recognized in earnings in the coming 12 months.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Asset Derivatives as of September 30, |
|
|
|
2010 |
|
|
2009 |
|
|
|
Balance Sheet |
|
|
|
|
|
Balance Sheet |
|
|
|
|
|
|
Location |
|
Fair Value |
|
|
Location |
|
|
Fair Value |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest rate contracts caps |
|
Other Assets |
|
$ |
3 |
|
|
|
|
|
|
$ |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total derivatives |
|
|
|
$ |
3 |
|
|
|
|
|
|
$ |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liability Derivatives as of September 30, |
|
|
|
2010 |
|
|
2009 |
|
|
|
Balance Sheet |
|
|
|
|
|
Balance Sheet |
|
|
|
|
|
|
Location |
|
Fair Value |
|
|
Location |
|
|
Fair Value |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest rate contracts swaps |
|
Other Long-Term Liabilities |
|
$ |
(711 |
) |
|
|
|
|
|
$ |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total derivatives |
|
|
|
$ |
(711 |
) |
|
|
|
|
|
$ |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the three and nine months ended September 30, |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amount of Gain |
|
|
|
|
|
|
|
|
|
|
|
|
|
Amount of Gain |
|
|
Location of |
|
or (Loss) |
|
|
|
Amount of Gain or |
|
|
Location of Gain |
|
or (Loss) |
|
|
Gain or (Loss) |
|
Recognized in |
|
|
|
(Loss) |
|
|
or (Loss) |
|
Reclassified from |
|
|
Recognized in |
|
Income on |
|
Derivatives in ASC |
|
Recognized in |
|
|
Reclassified from |
|
Accumulated OCI |
|
|
Income on |
|
Derivative |
|
815 Cash Flow |
|
OCI on Derivative |
|
|
Accumulated OCI |
|
into Income |
|
|
Derivative |
|
(Ineffective |
|
Hedging |
|
(Effective Portion) |
|
|
into Income |
|
(Effective Portion) |
|
|
(Ineffective |
|
Portion) |
|
Relationships |
|
2010 |
|
|
2009 |
|
|
(Effective Portion) |
|
2010 |
|
|
2009 |
|
|
Portion) |
|
2010 |
|
|
2009 |
|
Interest rate contracts |
|
$ |
(805 |
) |
|
$ |
|
|
|
Interest Expense |
|
$ |
|
|
|
$ |
|
|
|
Interest Expense |
|
$ |
(9 |
) |
|
$ |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
(805 |
) |
|
$ |
|
|
|
|
|
$ |
|
|
|
$ |
|
|
|
|
|
$ |
(9 |
) |
|
$ |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
31
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
18. Other Charges
During the third quarter of 2010, the Company incurred other charges of $85, primarily
consisting of $50 in headcount reduction costs and $36 associated with lease abandonments, which
were abandoned in the third quarter of 2009.
Other charges by segment are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
Nine Months Ended |
|
|
|
September 30, |
|
|
September 30, |
|
|
|
2010 |
|
|
2009 |
|
|
2010 |
|
|
2009 |
|
Upstream Oil & Gas |
|
$ |
12 |
|
|
$ |
1,554 |
|
|
$ |
331 |
|
|
$ |
6,305 |
|
Downstream Oil & Gas |
|
|
73 |
|
|
|
864 |
|
|
|
367 |
|
|
|
1,902 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other charges |
|
$ |
85 |
|
|
$ |
2,418 |
|
|
$ |
698 |
|
|
$ |
8,207 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other charges incurred during the three and nine months ended 2009 include $276 and $4,958,
respectively, related to headcount reductions within corporate operations and have been allocated
to the Companys business segments based on a percentage of total revenue.
The accrual at September 30, 2010, for carrying costs of the abandoned lease space totaled
$935, consisting of $827 in Other current liabilities and $108 in Other long-term liabilities
on the Consolidated Balance Sheets. The Company estimates carrying costs of the abandoned lease
space based on an assessment of applicable commercial real estate markets. There may be a
significant fluctuation in the estimated costs to the extent the evaluation of the facts,
circumstances and expectations change. The principal variables in estimating the carrying costs are
the length of time required to sublease the space, the sublease rate and expense for inducements
(e.g., rent abatement, tenant improvement allowance) that may be offered to a prospective sublease
tenant. While the Company believes this accrual is adequate, it is subject to adjustment as
conditions change. The Company will continue to evaluate the adequacy of the accrual and will make
the necessary changes to the accrual as conditions warrant.
Activity in the accrual related to other charges for the period ended September 30, 2010 is as
follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Non- |
|
|
|
|
|
|
|
|
|
|
Cancelable |
|
|
|
|
|
|
Employee |
|
|
Lease and |
|
|
|
|
|
|
Termination |
|
|
Other |
|
|
|
|
|
|
and Other |
|
|
Contractual |
|
|
|
|
|
|
Benefits |
|
|
Obligations |
|
|
Total |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accrued cost at December 31, 2009 |
|
$ |
2,080 |
|
|
$ |
2,325 |
|
|
$ |
4,405 |
|
Costs recognized during 2010 |
|
|
538 |
|
|
|
300 |
|
|
|
838 |
|
Cash payments |
|
|
(1,399 |
) |
|
|
(1,537 |
) |
|
|
(2,936 |
) |
Non-cash charges (1) |
|
|
(281 |
) |
|
|
(13 |
) |
|
|
(294 |
) |
Change in estimates |
|
|
|
|
|
|
(140 |
) |
|
|
(140 |
) |
|
|
|
|
|
|
|
|
|
|
Accrued cost at September 30, 2010 |
|
$ |
938 |
|
|
$ |
935 |
|
|
$ |
1,873 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
|
Non-cash charges consist of $281 of accelerated stock-based compensation and $13
of accretion expense. |
19. Discontinuance of Operations, Asset Disposals, and Transition Services Agreement
Strategic Decisions
In 2006, the Company announced that it intended to sell its assets and operations in Nigeria
and classified these operations as Discontinued Operations. The net assets and net liabilities
related to the Discontinued Operations are shown on the Consolidated Balance Sheets as Liabilities
of discontinued operations. The results of the Discontinued Operations are shown on the
Consolidated Statements of Income as Income (loss) from discontinued operations, net of provision
for income taxes for all periods presented.
32
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
19. Discontinuance of Operations, Asset Disposals, and Transition Services Agreement (continued)
Nigeria Assets and Nigeria-Based Operations
Share Purchase Agreement
On February 7, 2007, Willbros Global Holdings, Inc., formerly known as Willbros Group, Inc., a
Panama corporation (WGHI), which is now a subsidiary of the Company and holds a portion of the
Companys non-U.S. operations, sold its Nigeria assets and Nigeria-based operations in West Africa
to Ascot Offshore Nigeria Limited (Ascot), a Nigerian oilfield services company, for total
consideration of $155,250 (later adjusted to $130,250). The sale was pursuant to a Share Purchase
Agreement by and between WGHI and Ascot dated as of February 7, 2007 (the Agreement), providing
for the purchase by Ascot of all of the share capital of WG Nigeria Holdings Limited (WGNHL), the
holding company for Willbros West Africa, Inc. (WWAI), Willbros (Nigeria) Limited, Willbros
(Offshore) Nigeria Limited and WG Nigeria Equipment Limited.
In connection with the sale of its Nigeria assets and operations, WGHI and WII, another
subsidiary of the Company, entered into an indemnity agreement with Ascot and Berkeley Group plc
(Berkeley), the parent company of Ascot (the Indemnity Agreement), pursuant to which Ascot and
Berkeley agreed to indemnify WGHI and WII for any obligations incurred by WGHI or WII in connection
with the parent company guarantees (the Guarantees) that WGHI and WII previously issued and
maintained on behalf of certain former subsidiaries now owned by Ascot under certain working
contracts between the subsidiaries and their customers. Either WGHI, WII or both may be
contractually obligated, in varying degrees, under the Guarantees with respect to the performance
of work related to several ongoing projects. Among the Guarantees covered by the Indemnity
Agreement are five contracts under which the Company estimates that, at February 7, 2007, there was
aggregate remaining contract revenue, excluding any additional claim revenue, of $352,107 and
aggregate estimated cost to complete of $293,562. At the February 7, 2007 sale date, one of the
contracts covered by the Guarantees was estimated to be in a loss position with an accrual for such
loss of $33,157. The associated liability was included in the liabilities acquired by Ascot and
Berkeley.
Approximately one year after the sale of the Nigeria assets and operations, WGHI received its
first notification asserting various rights under one of the outstanding parent guarantees. On
February 1, 2008, WWAI, the Ascot company performing the West African Gas Pipeline (WAGP)
contract, received a letter from West African Gas Pipeline Company Limited (WAPCo), the owner of
WAGP, wherein WAPCo gave written notice alleging that WWAI was in default under the WAGP contract,
as amended, and giving WWAI a brief cure period to remedy the alleged default. The Company
understands that WWAI responded by denying being in breach of its WAGP contract obligations, and
apparently also advised WAPCo that WWAI requires a further $55 million, without which it will not
be able to complete the work which it had previously undertaken to perform. The Company
understands that, on February 27, 2008, WAPCo terminated the WAGP contract for the alleged
continuing non-performance of WWAI.
Also, in February 2008, WGHI received a letter from WAPCo reminding WGHI of its parent
guarantee on the WAGP contract and requesting that WGHI remedy WWAIs default under that contract,
as amended. WGHI responded to WAPCo, consistent with its earlier communications, that, for a
variety of legal, contractual, and other reasons, it did not consider the prior WAGP contract
parent guarantee to have continued application. In February 2009, WGHI received another letter from
WAPCo formally demanding that WGHI pay all sums payable in consequence of the non-performance by
WWAI with WAPCo and stating that quantification of that amount would be provided sometime in the
future when the work was completed. In spite of this letter, the Company continued to believe that
the parent guarantee was not valid. WAPCo disputes WGHIs position that it is no longer bound by
the terms of WGHIs prior parent guarantee of the WAGP contract and has reserved all its rights in
that regard.
On February 15, 2010, WGHI received a letter from attorneys representing WAPCo seeking to
recover from WGHI under its prior WAGP contract parent company guarantee for losses and damages
allegedly incurred by WAPCo in connection with the alleged non-performance of WWAI under the WAGP
contract. The letter purports to be a formal notice of a claim for purposes of the Pre-Action
Protocol for Construction and Engineering Disputes under the rules of the High Court in London,
England. The letter claims damages in the amount of $264,834. At February 7, 2007, when WGHI sold
its Nigeria assets and operations to Ascot, the total WAGP contract value was $165,300 and the WAGP
project was estimated to be approximately 85.0 percent complete. The remaining costs to complete
the project at that time were estimated at slightly under $30,000. The Company is seeking to
understand the magnitude of the WAPCo claim relative to the WAGP projects financial status three
years earlier.
On August 2, 2010, the Company received notice that WAPCo had filed suit against WGHI under
English law in the London High Court on July 30, 2010, for the sum of $273,386. WGHI has several
possible defenses to this suit and intends to contest the matter vigorously, but the Company cannot
provide any assurance as to the outcome. The Company expects the litigation process to be lengthy.
33
WILLBROS GROUP, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(In thousands, except share and per share amounts)
(Unaudited)
19. Discontinuance of Operations, Asset Disposals, and Transition Services Agreement (continued)
The Company currently has no employees working in Nigeria and has no intention of returning to
Nigeria. If ultimately it is determined by an English Court that WGHI is liable, in whole or in
part, for damages that WAPCo may establish against WWAI for WWAIs alleged non-performance of the
WAGP contract, or if WAPCo is able to establish liability against WGHI directly under the parent
company guarantee, and, in either case, WGHI is unable to enforce rights under the indemnity
agreement entered into with Ascot and Berkeley in connection with the WAGP contract, WGHI may
experience substantial losses. However, at this time, the Company cannot predict the outcome of any
proceeding which may ensue in this developing WAGP contract dispute, or be certain of the degree to
which the indemnity agreement given in WGHIs favor by Ascot and Berkeley will protect WGHI.
Results of Discontinued Operations
For the three and nine months ended September 30, 2010, loss from Discontinued Operations was $578
and $1,324 or $0.01 and $0.03 per basic and diluted share, respectively. Although the Transition
Services Agreement expired on February 7, 2009, the Company continues to incur legal costs related
to the previously discussed WAPCo parent company guarantee assertions. For the three and nine
months ended September 30, 2009, loss from Discontinued Operations was $27 and $1,527 or $0.00 and
$0.04 per basic and diluted share, respectively.
34
ITEM 2. MANAGEMENTS DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (In
thousands, except share and per share amounts or unless otherwise noted)
The following discussion should be read in conjunction with the unaudited Condensed
Consolidated Financial Statements for the three and nine months ended September 30, 2010 and 2009,
included in Item 1 of this Form 10-Q, and the Consolidated Financial Statements and Managements
Discussion and Analysis of Financial Condition and Results of Operations, including Critical
Accounting Policies, included in our Annual Report on Form 10-K for the year ended December 31,
2009.
OVERVIEW
Third Quarter of 2010 Summary
In the third quarter of 2010, we generated revenue from continuing operations of $408,792 and
income of $35,986, or $0.71 per diluted share. The $161,259 (65.1 percent) increase in revenue as
compared to the second quarter of 2010 was primarily attributable to the inclusion of $158,173 of
revenue from our new Utility Transmission & Distribution (Utility T&D) segment which was
acquired on July 1, 2010 from InfrastruX Group, Inc. (InfrastruX). The third quarter net income
includes a non-cash item of $45,340 resulting from the reduction of a 2011 contingent earnout
liability, $45,340 after taxes. The earnout liability was originally calculated as part of the
March 11, 2010 agreement to purchase InfrastruX. A second non-cash item, a Downstream Oil & Gas
segment $12,000 goodwill impairment, $7,200 after taxes, is also included. Excluding the impact of
the $45,340 contingent earnout, the third quarter results were as follows:
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
|
September 30, |
|
|
|
2010 |
|
|
2009 |
|
Net income (loss) before special items (1) |
|
|
|
|
|
|
|
|
Net income, continuing operations |
|
$ |
35,986 |
|
|
$ |
1,683 |
|
Change in fair value of contingent earnout |
|
|
(45,340 |
) |
|
|
|
|
Goodwill impairment, net of taxes |
|
|
7,200 |
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss), continuing operations before special items |
|
$ |
(2,154 |
) |
|
$ |
1,683 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted income (loss) before special items (1) |
|
|
|
|
|
|
|
|
Continuing operations |
|
$ |
0.71 |
|
|
$ |
0.04 |
|
Income (loss) per share before special items |
|
$ |
(0.05 |
) |
|
$ |
0.04 |
|
|
|
|
|
|
|
|
|
|
Fully Diluted Shares |
|
|
|
|
|
|
|
|
Diluted shares as reported |
|
|
52,154,029 |
|
|
|
38,918,933 |
|
Diluted shares before special items(2) |
|
|
46,997,431 |
|
|
|
38,918,933 |
|
|
|
|
(1) |
|
Net income (loss), continuing operations before special items, a non-GAAP financial
measure, excludes special items that management believes affect the comparison of results for the
periods presented. Management also believes results excluding these items are more comparable to
estimates provided by securities analysts and therefore are useful in evaluating operational trends
of the company and its performance relative to other engineering and construction companies. |
|
(2) |
|
Excluding the special items would result in a net loss from continuing operations,
thus reclassifying all shares currently reported as dilutive to anti-dilutive. |
The Downstream Oil & Gas and the Upstream Oil & Gas segments had an operating loss of $11,606
and operating income of $26,980, respectively. Excluding the Downstream Oil & Gas segment goodwill
impairment, both of these segments showed successive quarter operating income improvements.
Utility T&D segment reported a $16,017 operating loss. Approximately one-half of this operating
loss is attributable to the July 1, 2010, InfrastruX acquisition deal costs of $7,901, and the
remainder of the loss relates to low activity levels and weak margins, primarily in the electric
and gas distribution businesses. Combining the operating income/loss of the three segments with
the previously referenced non-cash reduction in our contingent earnout liability results in third
quarter operating income of $44,697.
Downstream Oil & Gas segment would have reported operating income for the first time in the
past five quarters had the segment not taken the $12,000 goodwill impairment. The third quarter
operating results improved from the second quarter due to increased levels of maintenance and
turnaround activity and cost reduction measures. The recent quarter is encouraging, though the
expected increase in higher margin small capital projects was less than expected, with internal
forecasts indicating a continuing, though slower than previously expected improvement in the refining
sector. Management believes a goodwill impairment will occur when the scheduled December 1 annual
goodwill impairment review takes place. Management estimates the impairment at $12,000 and has
reflected this charge in the third quarter of 2010. The impairment is subject to finalization when
the full goodwill valuation review is completed in the fourth quarter.
In the Upstream Oil & Gas segment, we achieved excellent results in the third quarter,
primarily due to high utilization of U.S. resources and excellent
execution. Our Upstream Engineering revenue also increased in the third
quarter with utilization rates of approximately 90 percent. We view this increased engineering activity as a
precursor for more construction opportunities and expect good results in our Upstream Engineering business unit in the fourth quarter. Outside the
U.S., we executed additional time and material work in Oman and increased oil sands related activities in Canada for
field services, fabrication and our expanded chrome carbide overlay capacity. We also have two significant Canadian pipeline construction
projects in backlog extending our visibility
through first quarter of 2012. We have begun deploying resources to construct the Williams Energy Canada Boreal Pipeline and
construction on the Pembina Pipeline project is scheduled to begin in December with completion expected in mid-2011.
35
The Utility T&D segment reported an unanticipated earnings shortfall. This operating loss was
primarily due to a mix shift in transmission construction revenues associated with the Competitive
Renewable Energy Zone (CREZ) build out in Texas, resulting in a heavier mix of lower margin work
than anticipated. Additionally, work volumes on CREZ projects were lower versus expectations,
however, the CREZ initiative is ongoing and the ultimate timing for completion of these projects
has not changed. Operating costs as a percentage of revenue were higher as certain resources were
retained on jobs in anticipation of an uptick in volumes in the first quarter of 2011. The Utility
T&D segment results were also negatively impacted by delays in contract award and notice to proceed
on two large projects, including a large solar generation construction project in the Northeast,
both of which are now underway. The Utility T&D segment is expected to see growth in its
transmission construction business, but ongoing challenges impacting new real estate construction
is expected to continue to depress the distribution component of the business. Included in third
quarter operating results are $7,901 of transaction expenses associated with the acquisition of
InfrastruX.
We entered into a new credit
agreement (the “2010 Credit Agreement”) that provides for a
$475,000 senior secured credit facility, consisting of a four year,
$300,000 term loan facility (“Term Loan”) and a three year
revolving credit facility of $175,000 (the “2010 Credit Facility”)
as part of the InfrastruX acquisition. Third quarter earnings were negatively
impacted by a $9,007 increase in interest expense related to the Term Loan and
amortization of debt issuance costs.
Total backlog increased by $608,130 from $433,438 at June 30, 2010 to $1,041,568 at September
30, 2010, driven by the addition of $516,849 in backlog associated with our Utility T&D segment as
well as increases in both our Downstream Oil & Gas segment and Upstream Oil & Gas segment of
$33,601 and $57,680, respectively. Downstream Oil & Gas segment backlog improvement is mainly
attributable to increases in government services, tanks and refinery turnaround work. Upstream Oil
& Gas segment continues to realize backlog improvements in Canada and in engineering. The
engineering backlog increase is noteworthy as a precursor of an improving Upstream Oil & Gas
segment business cycle.
InfrastruX
On July 1, 2010, we completed the acquisition of InfrastruX. InfrastruX is an electric power
and natural gas transmission and distribution contractor with service delivery capabilities from
regional operating centers based primarily in the South Central, Midwest and East Coast energy
corridors. The acquisition is expected to result in increased scale, fostering our strategic
objectives for growth, diversity and stability. We believe this acquisition gives Willbros a
leadership position in the large U.S. electric transmission and distribution market, for which
forecasted capital investment is expected to exceed $56 billion through 2020.
In the short-term, we have experienced unanticipated delays in our transmission work that have
resulted in operating losses. We believe these short-term issues will
be resolved in the first half of 2011.
While weathering these difficult market conditions, we have begun the
integration
process to capture and further identify business synergies that will
improve our going forward results. We are evaluating the
creation of a new midstream business built on business units from the Upstream Oil & Gas and
Utility T&D segment, combining offices to reduce G&A costs, monetizing idle or underutilized
equipment and optimizing our market exposure and service delivery costs.
Continued Cost Containment
We have made significant progress due to our ongoing efforts to improve margins in our
Downstream Oil & Gas segment. Recognizing the sustained diminished market opportunities in our
Downstream Oil & Gas segment, we have implemented management changes and additional cost reductions
to better align the business with the constrained spending and margin pressure evident in
maintenance activities and, especially, small capital projects. We expect these changes to result
in annual savings of approximately $3,000 in 2011. We continue to monitor our operating expenses
and implement cost savings actions as necessary for future efficiencies.
Recent positive market indicators make us cautiously optimistic about the near term and
encouraged about the longer term outlook for Willbros. We believe we have advanced our strategy to
provide growth and diversify the revenue stream with the completion of the InfrastruX acquisition. As we move into a
business environment which places high value on efficiency, we are confident in the organization
and its ability to provide safety, quality, schedule certainty and valuebased solutions to the
global marketplace at competitive prices.
Our Vision
We continue to believe that long-term fundamentals support increasing demand for our services
and substantiate our vision for Willbros to be a diversified, global provider of professional
engineering, construction and maintenance solutions addressing the entire asset lifecycle of global
energy infrastructure.
To accomplish this, we are actively working towards achieving the following objectives:
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Integrating the InfrastruX
acquisition, which we believe advances our desire to diversify our end markets
and geographic exposure to better serve clients and mitigate market specific
risk; |
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Increasing professional services (project/program management, engineering, design,
procurement and logistics) capabilities to minimize cyclicality and risk associated with
large capital projects in favor of recurring service work; |
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Positioning Willbros as a service provider and employer of choice; |
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Developing long-term client partnerships and alliances by exceeding performance
expectations and focusing team driven sales efforts on key clients; and |
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Establishing industry best practices, particularly for safety and performance. |
36
Our Values
We believe the values we adhere to as an organization shape the relationships and performance
of our company. We are committed to strong leadership across the organization to achieve
Excellence, Accountability and Compliance in everything we do, based on and guided by our core
values of:
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Safety always perform safely for the protection of our people and our stakeholders; |
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Honesty & Integrity always do the right thing; |
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Our People respect and care for their well being and development; maintain an
atmosphere of trust, empowerment and teamwork; ensure the best people are in the right
position; |
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Our Customers understand their needs and develop responsive solutions; promote
mutually beneficial relationships and deliver a good job on time; |
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Superior Financial Performance deliver earnings per share and cash flow and maintain
a balance sheet which places us at the forefront of our peer group; |
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Vision & Innovation understand the drivers of our business environment; promote
constant curiosity, imagination and creativity about our business and opportunities; seek
continuous improvement; and |
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Effective Communications present a clear, consistent and accurate message to our
people, our customers and the public. |
We believe that adhering to and living these values will result in a high performance
organization which can differentiate and compete effectively, providing incremental value to our
customers, our employees and all our stakeholders.
Our Strategy
We work diligently to apply these values every day and use them to guide us in the development
and execution of our strategy which we believe will increase stockholder value by leveraging the
full resources and core competencies of an integrated Willbros business platform. Key elements of
our strategy are as follows:
Stabilize the Revenue Stream with Recurring Services
We believe increasing the level of revenue generated by recurring services will make our
business model more predictable and allow us to reduce our dependence
on mega-sized large diameter pipeline projects which are
more cyclical in nature and allows us to profitably scale our
offerings to match the changing market conditions. To that end, we have emphasized our manage and maintain service offering
and continue to pursue new alliances with owner/operators of major
natural gas transmission and storage facilities, whereby we provide core teams of engineers and
project managers having the ability to flex with the engineering and project management needs of
the client. Our July 2010 acquisition of InfrastruX also significantly increases our recurring
services component through the high level of revenue generated by Master Service Agreements
(MSAs), which account for nearly 75 percent of its revenue.
Focus on Managing Risk
We have implemented a core set of business conduct, practices and policies that have
fundamentally improved our risk profile. Examples include diversifying our service offerings and
end markets to reduce any market specific exposure, and focusing on contract execution risk
starting with our opportunity review process and ending at job completion. In todays economic
environment, acknowledging the importance of risk management is paramount to success. It is
emphasized throughout our organization and covers all aspects of a project from strategic planning
and bidding to contract management and financial reporting.
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Focus resources in markets with the highest risk-adjusted return. The majority of our
resources are focused on North America as we believe North America continues to offer us
significant opportunities with attractive risk-adjusted returns. Opportunities for our
expanded service offerings are expected to result from the ongoing development of
unconventional gas production in shale gas plays, increased emphasis on the maintenance and
integrity of existing infrastructure and facilities, high value-added small capital
projects to meet environmental, regulatory and product slate requirements in the refining
sector, and new electric infrastructure development opportunities. We will focus on
integration and optimization of our complementary service offerings to deliver superior
results. |
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Our operations are currently concentrated in North America, and we have examined the
global markets for opportunities to further diversify our geographic footprint into
international markets that provide attractive risk-adjusted returns. We have concluded that
North America continues to offer the most attractive risk-adjusted returns. Our extensive
international experience remains a differentiator for us and we will continue to
selectively pursue international opportunities. |
37
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Maintain a conservative contract portfolio and limit contract execution risk. While we will
continue to pursue a balanced contract portfolio, current market dynamics indicate our U.S.
pipeline operations, as
well as other service offerings, are in a much more competitive period, characterized by
competitive pricing and more fixed price contracts. We believe our fixed price execution
experience, our recent initiatives to realign our cost structure to the rapidly changing
market, our improved systems and our ongoing focus on risk management provide us a
competitive advantage versus many of our competitors. We prefer to maintain a smaller,
risk-limited project portfolio.
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Configure operating segments to minimize market risk. We have recognized and responded
to shifts in the markets addressed by both our Upstream Oil & Gas and Downstream Oil & Gas
segments by reducing equipment and personnel levels to hold certain resources, key teams
and skill sets and maximize their chargeability, keeping in mind future opportunities and
commitments. We are currently addressing our Utility T&D market and corresponding
requirements as we have previously done with our other two segments. |
Leverage Industry Position and Reputation into a Broader Service Offering
We believe the long term dynamics supporting the global energy infrastructure market will
continue to provide attractive opportunities. Our established service platform, capabilities and track record
position us to expand our expertise into a broader range of related service offerings. We intend to
leverage our project management, engineering and construction skills to provide additional service
offerings, such as instrumentation and electrical services, turbo-machinery services and
environmental services, and to enhance our ability to offer sole source solutions and develop
alliances and frame agreements with strategic customers. We believe that a more balanced mix of
recurring services, such as program management and maintenance services, together with our
traditional project work, will enhance the earnings profile of our business.
We have pursued selective acquisitions to complement our organic expansion strategies and to
reduce our dependence on the cyclical large-diameter cross-country pipeline construction market. We
began this process in 2007 with the InServ and Midwest acquisitions that expanded our service
offerings as well as the geographies where we deliver those services. Our July 2007 acquisition of
Midwest significantly enhanced our presence in mainline pipeline construction in Western Canada.
Our November 2007 acquisition of InServ complemented our service offerings to our traditional
market of engineering and construction services in the midstream hydrocarbon transportation
industry. In July 2009, our acquisition of the engineering business of Wink Companies, LLC, (Wink
or Downstream engineering business unit), when combined with our existing downstream offering,
created a platform to provide integrated engineering, procurement and construction (EPC),
services to the downstream market, mirroring our upstream capabilities. More recently, on July 1,
2010, we closed on the acquisition of InfrastruX, an electric power and natural gas transmission
and distribution contractor with service delivery capabilities from regional operating centers
based primarily in the South Central, Midwest and East Coast energy corridors. We believe this
acquisition gives Willbros a leadership position in the large and fast growing market for electric
transmission infrastructure as well as completing our capability to provide fully integrated
services from engineering through construction and integrity services for the full spectrum of
natural gas transmission and distribution. Our near term focus will be on integration and
optimization of this transformational acquisition. We take a long term perspective on acquisitions
which we believe will build strong, diversified platforms to drive future stockholder value.
Maintain Financial Flexibility
Maintaining the financial flexibility to meet the material, equipment and personnel needs to
support our project commitments, as well as the ability to pursue our expansion and diversification
objectives, is critical to our growth. We view financial strength and flexibility as a fundamental
requirement to fulfilling our strategy. As of September 30,
2010, we had cash and cash equivalents of $100,887. On July 1, 2010
and as part of the transaction financing for the acquisition of
InfrastruX, we entered into the 2010 Credit Agreement that provides for a $475,000 senior secured credit
facility, consisting of a four year, $300,000 Term Loan and a three year revolving credit facility of $175,000. The 2010 Credit Agreement
replaces our existing three-year $150,000 senior secured credit facility, which was scheduled to
expire in November 2010.
38
Leverage Core Service Expertise into Additional Full EPC Contracts
Our core expertise and service offerings allow us to provide our customers with a single
source EPC solution which creates greater efficiencies to the benefit of both our customers and our
company. We believe our upstream EPC and our downstream EPC, which are focused on small to
mid-sized capital projects, are relatively unique in our respective markets, providing us with a
competitive advantage in providing these services. In performing integrated EPC contracts, we often
perform front-end engineering and design services while
establishing ourselves as overall project managers from the earliest stages of project
inception and are, therefore, better able to efficiently determine the design, permitting,
procurement and construction sequence for a project in connection with making engineering
decisions. Our customers benefit from a more seamless execution; while for us, these contracts
often yield consistent profit margins on the engineering and construction components of the
contract compared to stand-alone contracts for similar services. Additionally, this contract
structure allows us to deploy our resources more efficiently and capture the engineering,
procurement and construction components of these projects. The acquisition of Wink enabled us to
provide EPC services to the downstream market, thus mirroring our upstream capabilities.
Our Business
We are a provider of services to global end markets serving the oil and gas, refinery,
petrochemical and power industries. Our services, which include engineering, procurement and
construction, either individually or together as an integrated EPC service offering, turnaround,
maintenance and other specialty services, are critical to the ongoing expansion and operation of
energy infrastructure. With over 100 years of experience in the global energy infrastructure
market, our full asset lifecycle services are utilized by major pipeline transportation companies,
exploration and production companies and refining companies as well as government entities
worldwide.
Within the global energy infrastructure market, we specialize in designing, constructing,
upgrading and repairing onshore and coastal midstream assets such as pipelines,
compressor/pumping stations and other related facilities as well as downstream facilities, such as refineries.
Through our legacy international pipeline construction business we have constructed approximately
124,000 miles (200,000 kilometers) of pipelines in our history, building a global reputation for
performing quality work on time, often under challenging conditions. Depending upon market
conditions and our assessment of an appropriate risk-adjusted return, we may work in developing
countries. Having performed work in over 60 countries, we believe our experience gives us a
competitive advantage in frontier areas where experience in dealing with project logistics is an
important consideration for project award and execution.
We complement our pipeline construction market expertise with service offerings to the
downstream hydrocarbon processing market, providing integrated solutions for turnaround,
maintenance and capital projects for the refining and petrochemical industries. We also provide
specialty turnaround services, tank services, heater services, construction services, safety
services and fabricate specialty items for hydrocarbon processing units. We have performed these
downstream services for over 100 of the refineries in the United States and have experience in
certain international markets. We offer our clients full asset lifecycle services and, in some
cases, provide the entire scope of services for a project, from front-end engineering and design to
procurement, construction, and commissioning as well as ongoing facility operations and
maintenance. We believe our engineering, planning and project management expertise, as it relates
to optimizing the structure and execution of a project, provide us with competitive advantages in
the markets we serve.
Our acquisition of InfrastruX in July 2010 expands our service offering to include
construction and maintenance of electric transmission and distribution systems. Additionally, the
InfrastruX acquisition has expanded our service offering of small diameter pipe installation
capabilities for both gathering and city distribution and our geographic presence now encompasses
virtually all of the non-conventional hydrocarbon plays in North America.
Significant Business Developments
InfrastruX Acquisition. On July 1, 2010, we completed the acquisition of 100 percent of the
outstanding stock of InfrastruX for a purchase price of approximately $486,000, before final
working capital and other transaction adjustments. We paid approximately $372,400 in cash, a
portion of which was used to retire InfrastruX indebtedness and pay InfrastruX transaction
expenses, and issued approximately 7.9 million shares of the Companys common stock to the
shareholders of InfrastruX. Cash paid was comprised of approximately $72,400 in cash from
operations and $300,000 from the Term Loan. The acquisition was completed pursuant to an Agreement
and Plan of Merger (the Merger), dated March 11, 2010. Included in the purchase price is
approximately $55,340 of contingent consideration, estimated as of the acquisition date. Under the
terms of the agreement, contingent consideration of up to $125,000 may be earned over a two year
period in the event InfrastruX meets specified adjusted EBITDA targets, with initial thresholds of
approximately $69,825 and $80,000 in 2010 and 2011, respectively.
InfrastruX is a provider of electric power and natural gas transmission and distribution
maintenance and construction solutions to customers primarily from their regional operating centers in the
South Central, Midwest and East Coast regions of the United States. This acquisition significantly
diversifies our capabilities and end markets. In addition to providing meaningful access to the
attractive electric transmission and distribution market, the acquisition also expands the breadth
of our natural gas capabilities and better positions us in targeted markets such as the Marcellus
shale play. InfrastruX and its results of operations in the electric transmission and distribution
end markets are included in a newly established segment, Utility T&D. Any goodwill recognized
through this transaction will be allocated to this segment, which will also be the reporting
unit. Goodwill associated with this transaction is not expected to be deductible for tax purposes.
39
The acquisition of InfrastruX diversifies our end-market exposure while expanding our
capabilities into attractive geographies, including the Marcellus shale region where we are already
expanding our presence and are providing services to a major alliance partner, and more liquids
oriented plays such as the Eagle Ford and Bakken shales. The combination creates a higher component
of recurring services and provides additional stability, through the many MSAs InfrastruX has in
place, with longstanding client relationships, some as long as 50 years. In addition, we believe
this acquisition will allow us to offer the complementary pipeline services of a larger InfrastruX
subsidiary that is focused on smaller diameter, distribution and pipe-related field services. We
believe the market for pipeline systems construction services will be characterized by more
projects of smaller scope and scale, and that the combination of our large diameter pipeline
construction, project management and engineering expertise with the InfrastruX model will better
meet client needs and expectations going forward. We also recognize market fundamentals which lead
us to believe the national transmission grid in the United States will undergo significant
expansion to meet reliability goals and link new, renewable generation with distant end markets.
Our new Utility T&D segment should benefit from our established and proven project management
systems as we apply them to major electric transmission line construction opportunities.
Finally, this transaction significantly adds to our scale. We believe customers today are
favoring players with the capabilities to provide a broader and more integrated set of services.
With the larger geographic footprint, complementary service offerings and client bases, the
InfrastruX acquisition broadens our prospects with additional cross-selling and integrated EPC
opportunities.
Williams Energy Canada Boreal Pipeline. In June 2010, our Canadian business was awarded
construction of the Williams Energy Canada Boreal Pipeline. The new 12-inch diameter pipeline will
transport high vapor pressure liquids approximately 420 km from Williams Liquid Extraction Plant
north of Fort McMurray to their Redwater Olefins Facility northeast of Edmonton, Alberta.
Construction will be completed in three construction seasons commencing in the fall of 2010 with
final completion in the spring of 2012. This project commenced in the third quarter.
Fayetteville Express Project (FEP). On April 1, 2010, we commenced work on the construction
contract for spreads three and four of the FEP project. The approximately 185-mile natural gas
pipeline originates in Conway County, Arkansas, continues eastward through White County, Arkansas,
and terminates at an interconnection with Trunkline Gas Company in Panola County, Mississippi. FEP
parallels existing utility corridors, where possible, to minimize the impact to the environment,
communities and landowners. FEP is a joint venture between Energy Transfer Partners, L.P. and
Kinder Morgan Energy Partners, L.P. Our scope of work includes 120 miles of 42-inch pipeline,
beginning near Bald Knob, Arkansas and ending at the Trunkline interconnection. At September 30,
2010, this project was substantially complete, with only clean-up and punch list items remaining to
be accomplished.
Nipisi Pipeline Project. In September 2010, Willbros Canada executed a contract to perform
construction of Spread C for Pembina Pipeline Corporations Nipisi & Mitsue Pipeline Projects.
Willbros will construct approximately 90 km of dual 20 inch and 8 inch pipeline near Slave Lake,
Alberta. Construction is scheduled to begin in December and the pipeline is expected to be in
service in mid-2011. The two pipelines will expand Pembinas operating system in the vicinity of
Whitecourt, Swan Hills, Slave Lake and north to the existing Nipisi Terminal.
Pembina Pump Stations. In August 2010, Pembina Pipeline Corporation awarded Willbros Canada a
project for the construction of six pump stations for the Nipisi Heavy Crude Pipeline Project.
The scope of work includes site grading at select sites, piling, pipe rack, process pipe,
installation of process pumps, underground drain tanks, concrete work and site fencing. The project
began in August 2010 and is scheduled for completion in February 2011.
Oxy Elk Hills. In September 2010, CB&I selected our Upstream Oil & Gas segment to provide EPC
of 45 miles of export pipelines associated with a new gas processing plant to be owned and operated
by Occidental of Elk Hills, Inc. CB&I has been awarded the engineering, procurement and
construction of the new processing plant at the Elk Hills oil and gas field in central California.
The Willbros portion of the total project is valued in excess of $40 million.
McKee Flare Gas Recovery. Diamond Shamrock Refining Company selected our Downstream Oil & Gas
segment to provide EPC of the new Flare Gas Recovery Facilities at the Valero McKee Refinery
located in Sunray, Texas. The project is valued at approximately $14 million.
Defense Logistics. In September 2010, Willbros Government Services (U.S.) LLC, was awarded a
contract for approximately $28 million by the Defense Logistics Agency-Energy (DLA-Energy) to
design, build, own, and operate six automated fuel dispensing facilities at Camp Pendleton,
California. The five-year contract includes options for three additional five-year periods. The
facility will provide petroleum products and services for government operations.
40
NAVFAC Task Orders. In August 2010, the Naval Facilities Engineering Command (NAVFAC) awarded
Willbros Government Services five separate task orders under its global $350 million multiple-award
indefinite delivery-indefinite quantity (IDIQ) construction and construction services contract for
Petroleum, Oil and Lubricant (POL) fuel systems. The task orders include various inspections,
construction and repair at Eielson Air Force Base, AK; Misawa Air Force Base, Japan; Naval Air
Station Oceana, Virginia Beach, VA; Naval Support Activity, Panama City, FL; and Naval Air Weapons
Station, China Lake, CA. The work began in August and is scheduled for completion in early 2011.
Goodwill Impairment
In accordance with Accounting Standard Codification (ASC) 350 Goodwill and Other
Intangible Assets, we perform our required annual impairment test for goodwill each year, effective
December 1. In connection with the 2009 annual test, the estimated fair value of our Downstream Oil
& Gas segment exceeded its carrying value by 1.0 percent. As disclosed in our 2009 Form 10-K, we
continue to monitor the carrying value of this segment. We continue to experience reduced demand
for services resulting from the current low level of both capital and maintenance spending in the
refining industry, which has fostered a highly competitive environment, resulting in significantly
decreased margins.
During the third quarter, in connection with the completion of our preliminary forecasts for
2011, it became evident that a goodwill impairment was probable. Using a discounted cash flow
analysis supported by comparative market multiples to determine the fair value of the segment
versus its carrying value, a range of likely impairment was generated. The low end of this range
was approximately $12,000. Accordingly, we have recorded an impairment charge of $12,000 during
the third quarter of 2010. The charge reduces goodwill recorded in connection with the acquisition
of InServ in November 2007 and does not impact our business operations.
The third quarter charge was based on estimates made by management outside of Step One and
Step Two of our annual test for goodwill impairment. We will perform this test during the fourth
quarter of 2010. This may result in further impairment.
Change In Fair Value of Contingent Earnout Liability
During the third quarter of 2010, we recorded a $45,340 adjustment to the estimated fair value
of the contingent earnout liability. This change in estimated contingent earnout liability to the
former InfrastruX shareholders was due to a third quarter decrease in the probability-weighted
estimated achievement of EBITDA targets as set forth in the merger agreement. This reduction was
driven primarily by the following:
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Expectations for lower margins on major transmission projects due to (i) a shift in the
mix of projects in Texas towards lower margin projects than previously anticipated and (ii)
ongoing competition in other regions, particularly the northeast, as the pace of bid
activity has been slower than expected in returning to pre-2009 levels; |
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A slower than anticipated rebound in key housing markets continues to pressure work
volumes under existing MSAs and the budgets of many of our utility customers, while
increasing the competitive pricing on bids for new awards; and |
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Reduced expectations for significant storm work, which typically carries a higher margin
than our standard MSA work. |
In
accordance with ASC 805 Business Combinations, we review the contingent earnout liability
on a quarterly basis in order to determine its fair value. Changes in the fair value of the
liability are recorded within operating expenses in the period in which the change is made and the
liability may increase or decrease on a quarterly basis until the earnout period has concluded.
Financial Summary
Results and Financial Position
For the three months ended September 30, 2010, we recorded income from continuing operations
of $35,986, or $0.77 per basic and $0.71 per diluted share, on revenue of $408,792. This compares
to income from continuing operations of $1,683, or $0.04 per basic and diluted share, on revenue of
$247,533 for the same period in 2009. Our increase in profitability during the third quarter of
2010 as compared to the same quarter in 2009 was driven primarily due to the change in fair value
of the contingent earnout liability previously discussed. Excluding this change in fair value, our
results in the third quarter of 2010 were lower than the previous quarter due to the impairment of
goodwill associated with the Downstream Oil & Gas segment.
Revenue for the three months ended September 30, 2010 increased $161,259 (65.1 percent) to
$408,792 from $247,533 during the same period in 2009. The revenue increase was primarily
attributable to our newly acquired Utility T&D segment that reported third quarter revenues of
$158,173. Additionally, our Downstream Oil & Gas segment revenue increased $23,509 from improved
activity in maintenance and turnaround services and
our Upstream Oil & Gas segment revenue decreased $20,423 driven primarily by our Upstream Canadian
operations.
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General and Administrative costs for the third quarter of 2010 increased $17,878 (102.3
percent) to $35,347 as compared to $17,469 in the same quarter of 2009, as a result of additional
general and administrative costs associated with our newly acquired Utility T&D segment.
Operating income for the three months ended September 30, 2010 increased $7,858 (224.6 percent) to
$11,357, excluding the impact of the $45,340 change in fair value of contingent earnout
consideration and the $12,000 goodwill impairment charge at our Downstream Oil & Gas segment, from
$3,499 during the same period in 2009. The operating income increase was primarily attributable to
an operating income increase of $21,520 at our Upstream Oil & Gas segment and $394 at our
Downstream Oil & Gas segment, excluding the $12,000 goodwill impairment charge taken in the third
quarter of 2010. These increases were offset by our Utility T&D segment that reported a $16,017
operating loss. The primary causes of the year-over-year quarter variance by segment are:
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The Upstream Oil & Gas segment generated operating income of $26,980 in the third
quarter 2010, with operating margin of 15.9 percent, as compared to $5,460 and 2.9 percent,
respectively, in the third quarter 2009. The margin improvement was primarily driven by
fixed price work which did not suffer margin erosion experienced on cost reimbursable
fixed-fee contracts in the same period in 2009. Additionally, margins improved in 2010 as
a result of a quarterly reduction in depreciation expense of $1,606 due to the change in
the estimated useful life of certain construction equipment. This overall Upstream Oil &
Gas operating income improvement was partially offset by a 10.7 percent revenue reduction. |
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The Downstream Oil & Gas segment reported third quarter 2010 operating income of $394,
excluding the impact of the $12,000 goodwill impairment charge recorded in the third
quarter of 2010, a $2,355 increase from the same quarter in the prior year due to increased
maintenance and turnaround activity, recent management changes and cost savings initiated
in the second quarter 2010. See the table below for the reconciliation of the non-GAAP
presentation. |
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Three Months Ended |
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September 30, |
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2010 |
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2009 |
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Downstream Oil & Gas operating income,
as reported |
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$ |
(11,606 |
) |
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$ |
(1,961 |
) |
Goodwill impairment |
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12,000 |
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Downstream Oil & Gas operating income
before special items |
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$ |
394 |
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$ |
(1,961 |
) |
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The Utility T&D segment generated an operating loss of $16,017 during the third
quarter of 2010, primarily as a result of the previously mentioned acquisition-related
costs charged to this segment. Also impacting results were lower volumes and a mix shift
in transmission construction revenues associated with the CREZ build out in Texas,
resulting in a heavier mix of lower margin work than anticipated; delayed start up of two
significant projects in the northeast (both of which are currently underway); and in
general a weaker market for electric and gas distribution work. |
During the three months ended September 30, 2010, we recognized an income tax benefit of
$2,687 on income from continuing operations before income tax of $33,592. The tax benefit for the
three months ended September 30, 2010 was derived from the tax benefit recorded on the goodwill
impairment and reduced by the write-off of $299 in deferred tax assets related to tax benefits
previously recorded under ASC 718 Stock Compensation that will no longer be realized and $3,453
of InfrastruX deal costs that received no U.S. tax benefit. The $45,340 contingent liability
release had no tax effect.
Overall, our backlog has increased by $608,130, or 140.3 percent, from $433,438 at June 30,
2010 to $1,041,568 at September 30, 2010, mainly from the addition of $516,849 in backlog from our
Utility T&D segment. Also, we recognized increases of $57,680 and $33,601 in our Upstream Oil &
Gas and Downstream Oil & Gas segments, respectively.
Working capital as of September 30, 2010, for continuing operations decreased $78,241 (26.3
percent) to $219,053 from $297,294 at December 31, 2009, primarily as a result of cash paid for the
acquisition of InfrastruX and the movement of $58,006 of our 2.75% Convertible Senior Notes (the
2.75% Notes) to a current liability as the holders of our 2.75% Notes have the right to require us
to purchase the 2.75% Notes for cash, including unpaid interest, on March 15, 2011. Offsetting
these decreases was the addition of working capital of $77,670 related to our new Utility T&D
segment.
Our debt to equity ratio as of September 30, 2010, increased to 0.68:1 from 0.21:1 at December
31, 2009, primarily due to the issuance of the Term Loan facility in connection with the
acquisition of InfrastruX.
Consolidated cash flows during the nine months ended September 30, 2010, including
discontinued operations, decreased $133,746, to cash used by all activities of $97,887, from cash
provided by all activities of $35,859 during the same period in 2009. The decrease in cash is
primarily the result of an increase in cash consumed by operations and a decrease in working
capital attributable to the July 1, 2010 acquisition of InfrastruX.
Other Financial Measures
Backlog
In our industry, backlog is considered an indicator of potential future performance because it
represents a portion of the future revenue stream. Our strategy is focused on backlog additions and
capturing quality backlog with margins commensurate with the risks associated with a given project.
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Backlog consists of anticipated revenue from the uncompleted portions of existing contracts
and contracts whose award is reasonably assured. As we continue progressing our business model
towards increased emphasis on recurring services, which includes MSAs, our backlog estimates will
not reflect the full-term value of the contract. Estimated work under MSAs is included in backlog
for a period of 12 months or the remaining term of the contract, whichever is less. We determine
the amount of backlog for work under ongoing maintenance contracts, or MSAs, by using recurring
historical trends inherent in the MSAs, factoring in seasonal demand and projecting customer needs
based upon ongoing communications with the customer. We also include in backlog our share of work
to be performed under contracts signed by joint ventures in which we have an ownership interest.
Total backlog from continuing operations increased $649,826 from $391,742 at December 31, 2009
to $1,041,568 at September 30, 2010. In U.S. pipeline construction, we have transitioned back to a
more historically based backlog; unlike the period from 2007-2009 when the industry operated at or
near capacity which led to higher backlog levels as customers reserved available capacity up to a
year or more in advance of the project start date. Historically, a substantial amount of our
pipeline construction revenue in a given year has not been in our backlog at the beginning of that
year. Additionally, due to the short duration of many jobs, revenue associated with jobs performed
within a reporting period will not be reflected in quarterly backlog reports. We generate revenue
from numerous sources, including contracts of long or short duration, change orders, extra work,
variations in the scope of work and the effect of escalation or currency fluctuation formulas.
The following table shows our backlog by operating segment and geographic region as of
September 30, 2010 and December 31, 2009:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2010 |
|
|
December 31, 2009 |
|
|
|
Amount |
|
|
Percent |
|
|
Amount |
|
|
Percent |
|
Operating Segment |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Upstream Oil & Gas |
|
$ |
386,276 |
|
|
|
37.1 |
% |
|
$ |
245,586 |
|
|
|
62.7 |
% |
Downstream Oil & Gas |
|
|
138,443 |
|
|
|
13.3 |
% |
|
|
146,156 |
|
|
|
37.3 |
% |
Utility T&D |
|
|
516,849 |
|
|
|
49.6 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total backlog |
|
$ |
1,041,568 |
|
|
|
100.0 |
% |
|
$ |
391,742 |
|
|
|
100.0 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2010 |
|
|
December 31, 2009 |
|
|
|
Amount |
|
|
Percent |
|
|
Amount |
|
|
Percent |
|
Geographic Region |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
United States |
|
$ |
736,983 |
|
|
|
70.8 |
% |
|
$ |
358,808 |
|
|
|
91.6 |
% |
Canada |
|
|
254,731 |
|
|
|
24.5 |
% |
|
|
9,639 |
|
|
|
2.5 |
% |
Middle East/North Africa |
|
|
44,874 |
|
|
|
4.3 |
% |
|
|
23,295 |
|
|
|
5.9 |
% |
Other International |
|
|
4,980 |
|
|
|
0.4 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total backlog |
|
$ |
1,041,568 |
|
|
|
100.0 |
% |
|
$ |
391,742 |
|
|
|
100.0 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA and Adjusted EBITDA from Continuing Operations
We use EBITDA (earnings before net interest, income taxes, depreciation and amortization) as
part of our overall assessment of financial performance by comparing EBITDA between accounting
periods. We believe that EBITDA is used by the financial community as a method of measuring our
performance and of evaluating the market value of companies considered to be in businesses similar
to ours.
EBITDA from continuing operations for the three months ended September 30, 2010 increased
$64,522 (515.5 percent) to $77,038 from $12,516 during the same period in 2009. The increase in
EBITDA is primarily a result of increased contract income of $38,239 (excluding depreciation) and
an increase in contract margin of 4.4 percentage points for the three months ended September 30,
2010.
EBITDA from continuing operations for the nine months ended September 30, 2010 increased
$13,365 (17.1 percent) to $91,375 from $78,010 during the same period in 2009. The increase in
EBITDA during the nine months ended September 30, 2010 is primarily a result of the $45,340 change
in fair value of the contingent earnout liability recognized in the third quarter of 2010, offset
by decreased contract income of $13,866 (excluding depreciation).
In addition to EBITDA, management uses Adjusted EBITDA for:
|
|
|
Comparing normalized operating results with corresponding historical periods and
with the operational performance of other companies in our industry; and |
|
|
|
Presentations made to analysts, investment banks and other members of the financial
community who use this information in order to make investment decisions about us. |
43
Adjustments to EBITDA broadly consist of items which management does not consider
representative of the ongoing operations of the Company. These generally include costs or benefits
that are unusual, non-cash or one-time in nature. These adjustments are included in various
performance metrics under our credit facilities and other financing arrangements. The EBITDA
adjustments to determine Adjusted EBITDA are itemized in the following table. You are encouraged
to evaluate these adjustments and the reasons we consider them appropriate for supplemental
analysis. In evaluating Adjusted EBITDA, you should be aware that in the future we may incur
expenses that are the same as, or similar to, some of the adjustments in this presentation. Our
presentation of Adjusted EBITDA should not be construed as an inference that our future results
will be unaffected by unusual or non-recurring items.
EBITDA and Adjusted EBITDA are not financial measurements recognized under U.S. generally
accepted accounting principles, or U.S. GAAP, and when analyzing our operating performance,
investors should use EBITDA and Adjusted EBITDA in addition to, and not as an alternative for, net
income, operating income, or any other performance measure derived in accordance with U.S. GAAP, or
as an alternative to cash flow from operating activities as a measure of our liquidity. Because all
companies do not use identical calculations, our presentation of EBITDA and Adjusted EBITDA may be
different from similarly titled measures of other companies.
During the second quarter ended June 30, 2010, we modified some of our items to be included in
Adjusted EBITDA in the tables below in order to be more aligned with that of EBITDA as defined
under our 2010 Credit Agreement. Specifically, DOJ monitor costs are no longer added back, and
income attributable to our noncontrolling interest is now added back, to arrive at Adjusted EBITDA.
A reconciliation of EBITDA and Adjusted EBITDA from continuing operations to U.S. GAAP
financial information follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
Nine Months Ended |
|
|
|
September 30, |
|
|
September 30, |
|
|
|
2010 |
|
|
2009 |
|
|
2010 |
|
|
2009 |
|
Net income from continuing
operations attributable to Willbros
Group, Inc. |
|
$ |
35,986 |
|
|
$ |
1,683 |
|
|
$ |
32,057 |
|
|
$ |
27,578 |
|
Interest, net |
|
|
11,836 |
|
|
|
1,977 |
|
|
|
16,018 |
|
|
|
6,093 |
|
Provision (benefit) for income taxes |
|
|
(2,687 |
) |
|
|
(659 |
) |
|
|
(5,074 |
) |
|
|
13,257 |
|
Depreciation and amortization |
|
|
19,903 |
|
|
|
9,515 |
|
|
|
36,374 |
|
|
|
31,082 |
|
Goodwill impairment |
|
|
12,000 |
|
|
|
|
|
|
|
12,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA |
|
|
77,038 |
|
|
|
12,516 |
|
|
|
91,375 |
|
|
|
78,010 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock based compensation |
|
|
1,911 |
|
|
|
2,331 |
|
|
|
6,208 |
|
|
|
7,248 |
|
Restructuring and reorganization costs |
|
|
85 |
|
|
|
2,418 |
|
|
|
698 |
|
|
|
8,207 |
|
Acquisition related costs |
|
|
7,947 |
|
|
|
857 |
|
|
|
9,912 |
|
|
|
942 |
|
(Gains) losses on sales of equipment |
|
|
(106 |
) |
|
|
(865 |
) |
|
|
(1,791 |
) |
|
|
165 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Noncontrolling interest |
|
|
293 |
|
|
|
372 |
|
|
|
902 |
|
|
|
1,543 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted EBITDA |
|
$ |
87,168 |
|
|
$ |
17,629 |
|
|
$ |
107,304 |
|
|
$ |
96,115 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Discontinued Operations
In 2006, we announced our intention to sell our assets and operations in Nigeria, which led to
their classification as discontinued operations (Discontinued Operations). We sold our Nigeria
assets and operations on February 7, 2007 to Ascot Offshore Nigeria Limited (Ascot) pursuant to a
Share Purchase Agreement by and between us and Ascot.
Results
For the three months ended September 30, 2010, loss from Discontinued Operations was $578 or
$0.01 per basic and diluted share, compared to a loss of $27 or $0.00 per basic and diluted share,
for the three months ended September 30, 2009. For the nine months ended September 30, 2010, the
loss from Discontinued Operations was $1,324 or $0.03 per basic and diluted share compared to a
loss of $1,527 or $0.04 per basic and diluted share for the nine months ended September 30, 2009.
During the second quarter of 2009, a $1,750 charge was taken to write off the net book value of the
commitment related to the sale of our Venezuelan assets and operations as management determined the
collection of the outstanding commitment highly unlikely, due to nationalization of various
oil-field service contractors within the country.
Although the Transition Services Agreement expired on February 7, 2009, we continue to incur
legal fees related to the West African Gas Pipeline Company Limited (WAPCo) parent company
guarantee assertions as further discussed in Note 19 Discontinuance of Operations, Asset
Disposals, and Transition Services Agreement. These legal fees are expected to escalate and
continue over the next several years. At this time, we
are unable to estimate the likely total legal costs.
44
CRITICAL ACCOUNTING POLICIES AND ESTIMATES
In our Annual Report on Form 10-K for the year ended December 31, 2009, we identified and
disclosed our significant accounting policies. Subsequent to December 31, 2009, there has been no
change to our significant accounting policies other than the estimated useful life of construction
equipment as discussed in Note 1 The Company and Basis of Presentation.
For further information regarding new accounting pronouncements and accounting pronouncements
adopted in the first nine months of 2010, see Note 2 New Accounting Pronouncements.
RESULTS OF OPERATIONS
Our contract revenue and contract costs are significantly impacted by the capital budgets of
our clients and the timing and location of development projects in the oil, gas and power
industries worldwide. Contract revenue and cost vary by country from year-to-year as the result of:
(a) entering and exiting work countries; (b) the execution of new contract awards; (c) the
completion of contracts; and (d) the overall level of demand for our services.
Our ability to be successful in obtaining and executing contracts can be affected by the
relative strength or weakness of the U.S. dollar compared to the currencies of our competitors, our
clients and our work locations.
Three Months Ended September 30, 2010 Compared to Three Months Ended September 30, 2009
Contract Revenue
For the three months ended September 30, 2010, contract revenue increased $161,259 (65.1
percent) to $408,792 from $247,533 during the same period in 2009. A quarter-to-quarter comparison
of revenue is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three months ended September 30, |
|
|
|
|
|
|
|
|
|
|
|
Increase |
|
|
Percent |
|
|
|
2010 |
|
|
2009 |
|
|
(Decrease) |
|
|
Change |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Upstream Oil & Gas |
|
$ |
169,749 |
|
|
$ |
190,172 |
|
|
$ |
(20,423 |
) |
|
|
(10.7 |
)% |
Downstream Oil & Gas |
|
|
80,870 |
|
|
|
57,361 |
|
|
|
23,509 |
|
|
|
41.0 |
% |
Utility T&D |
|
|
158,173 |
|
|
|
N/A |
|
|
|
158,173 |
|
|
|
100.0 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
408,792 |
|
|
$ |
247,533 |
|
|
$ |
161,259 |
|
|
|
65.1 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Upstream Oil & Gas revenue decreased primarily related to a decrease in the volume of work
orders for a key recurring maintenance client in Canada, a slow summer construction season and
increased competition. In the United States revenue increased $2,817, or 2.7 percent, with the
largest increase, $18,892, being realized by our large diameter pipeline construction group,
followed by our pipeline specialty service group with an increase of $16,756, and our core
engineering services which increased $3,032. These increases were partially offset by the declines
in revenue from our facility construction group of $29,518 and our EPC work of $4,648. Our large
diameter pipeline construction group approached full utilization during the third quarter of 2010,
compared to two full months of work in the third quarter of 2009. Our pipeline specialty services
group experienced revenue growth of nearly seven times as we established our ability to serve
customers in the Haynesville shale region, performing multiple shorter length and smaller diameter
pipeline construction projects. Our engineering group exceeded their prior year revenue due to
continued strong demand for their services from our core customers. This was offset by the lack of
facility construction work performed during 2010 and the reduction of EPC work through the first
nine-months. It has been over one year between our last awarded EPC project and the recent award
that we received, valued at approximately $40 million.
In Canada, our revenue decreased $28,011, or 41.1 percent. This decrease impacted us across
our primary construction service offerings. Our field service groups revenue decreased $13,587,
our pipeline construction groups revenue decreased $7,722, and our facility construction groups
revenue decreased $5,924. The decrease in our field service revenue was primarily caused by the
reduced work volume for one of our key recurring maintenance clients. Our contract with this client
was scheduled to expire in the fourth quarter of 2010 and, as such, the client began decreasing the
volume of work orders for our services. On September 20, 2010, we received notification from the
client that we have been awarded the renewal of this contract. The revenue decrease for our
pipeline construction and facility construction groups was largely attributable to the slow summer
construction season and strong competition for this work in Canada. The winter construction season
is set to begin and our backlog is near maximum capacity for our pipeline construction group, with
over $150,000 in backlog. Additionally, we currently have over $16,000 in backlog for our facility
construction group.
In Oman, revenue increased by $4,773, or 29.3 percent due mainly to increased work volume from
our primary recurring service clients. The services we provide to these clients are directly
impacted by increased exploration and development spending in Oman.
45
Downstream Oil & Gas revenue increased primarily as a result of increased activity in
maintenance and turnaround services. We provided these services on twice as many turnarounds in
the third quarter (twelve) as compared to the same quarter in 2009. Total maintenance and
turnaround revenue increased $21,756 (105.2 percent) year-over-year in the third quarter. A
rescheduled significant second quarter of 2010 turnaround contributed $8,790 to the third quarter
revenue increase. Also contributing to the increased revenue was our expansion of service
capabilities in 2010 that allowed us to extract exchanger tube bundles, a service which was
performed on several turnarounds in the third quarter of 2010.
While the demand for our tank repair and maintenance services remains consistent with 2009, we
have experienced increased demand for new tank construction services in 2010. Revenue from tank
construction services increased $10,772 (154.2 percent) in the third quarter of 2010 compared to
the third quarter of 2009 as a result of several multiple-tank construction contract awards in the
United States and Canada in 2010.
The volume of government services work has also increased in 2010. These operations
experienced a $918 (95.1 percent) increase in revenue in the third quarter of 2010 compared to the
third quarter of 2009 as a result of task orders awarded by the U.S. Navy under the Engineering
Service Centers IDIQ contract.
These revenue increases were partially offset by decreased revenue from engineering and
construction services of $1,867 (13.9 percent) and $2,968 (67.8 percent), respectively. These
business units have experienced increased levels of bid activity on new capital work in 2010;
however, subsequent project awards have been slow to materialize, due in part to delayed contract
awards. This has also contributed to the $5,102 (46.6 percent) decrease in revenue experienced by
our fabrication facilities. The level of transfer line replacements has remained steady compared
to the third quarter of 2009; although, the demand for fabrication of process heaters has declined
as a result of decreased capital spending by our customers. We did, however, begin work late in
the third quarter of 2010 on an EPC project in Texas awarded by an existing customer.
Utility T&D revenue, a new segment, contributed $158,173 in revenue earned from July 1, 2010
through September 30, 2010 due to the acquisition of InfrastruX.
Operating Income
For the three months ended September 30, 2010, operating income decreased $4,142 (118.4
percent) to a loss of $643 from income of $3,499 during the same period in 2009. A
quarter-to-quarter comparison of operating income is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three months ended September 30, |
|
|
|
|
|
|
|
Operating |
|
|
|
|
|
|
Operating |
|
|
Increase |
|
|
Percent |
|
|
|
2010(1) |
|
|
Margin % |
|
|
2009 |
|
|
Margin % |
|
|
(Decrease) |
|
|
Change |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Upstream Oil & Gas |
|
$ |
26,980 |
|
|
|
15.9 |
% |
|
$ |
5,460 |
|
|
|
2.9 |
% |
|
$ |
21,520 |
|
|
|
394.1 |
% |
Downstream Oil & Gas |
|
|
(11,606 |
) |
|
|
(14.4 |
)% |
|
|
(1,961 |
) |
|
|
(3.4 |
)% |
|
|
(9,645 |
) |
|
|
(491.8 |
)% |
Utility T&D |
|
|
(16,017 |
) |
|
|
(10.1 |
)% |
|
|
N/A |
|
|
|
N/A |
|
|
|
(16,017 |
) |
|
|
(100.0 |
)% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
(643 |
) |
|
|
(0.2 |
)% |
|
$ |
3,499 |
|
|
|
1.4 |
% |
|
$ |
(4,142 |
) |
|
|
(118.4 |
)% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
|
This table does not reflect change in the fair value of contingent
earnout consideration of $45,340 in 2010 which is included in the operating results. The
change in fair value of contingent earnout consideration was characterized as a Corporate
change in estimate and is not allocated to the reporting segments. |
Upstream Oil & Gas operating income increased despite the 10.7 percent decrease in revenue.
This increase was primarily attributable to increased margins in U.S. operations, driven by fixed
price work which did not suffer from the margin erosion experienced due to cost escalation on cost
reimbursable fixed-fee contracts in the same period in 2009. The increase in margin in the United
States was partially offset by a slight decrease in margins in Canada and Oman.
For our United States operations, the two primary contributors to our margin increase were our
pipeline construction group and our engineering group. Our construction group substantially
completed the FEP project in the third quarter of 2010 as well as having seven significant projects
underway in the Haynesville shale area on smaller length and diameter pipeline construction
projects. Our margin improvement overall benefited from favorable weather conditions during the
third quarter of 2010, leading to high levels of productivity. Comparatively, in the third quarter
of 2009, one of our pipeline construction projects was in a loss position of approximately 17.1
percent. Additionally, our engineering group continued their strong performance in the third
quarter of 2010 with a utilization rate near 90 percent for the quarter. In comparison, in the
third quarter of 2009, we recorded $1,554 of other charges related to reducing staffing levels and
lease abandonments to meet the lower demand for our engineering services.
46
In Canada, our operating margins for the third quarter of 2010 decreased in comparison to the
same period in 2009. This decrease, combined with lower revenues, caused a reduction in our
operating income in Canada. The primary contributors to our margin decline were our pipeline
construction group and our facility construction group. Both groups experienced lower work volume
in 2010, causing lower utilization of resources and increased market pressure while bidding jobs.
These factors led to reduced margins. This decrease was partially offset by our field service group
which generated increased margins on significantly lower revenue. In Oman, we were able to
essentially maintain our margins while increasing revenue, generating more operating income, which
partially offset the decline in Canada.
Matching the reduction of revenue, we were able to hold our general and administrative costs
flat as a percent of revenue year-over-year at 6.7 percent. We will continue to monitor our general
and administrative costs and align them with our current opportunities in the markets in which we
participate.
Downstream Oil & Gas operating income decreased primarily as a result of the $12,000 goodwill
impairment charge taken in the third quarter of 2010. This decrease was offset by the previously
discussed increase in revenue from maintenance and turnaround services. Operating margins
increased 6.4 percent year-over-year in this business unit, due to cost cutting measures and
increased fixed price contract awards. Although we assumed the financial risk in performing these
fixed price contracts, we successfully managed both schedule and cost, while delivering quality
results for our customers.
The previously discussed decline in volume within our fabrication facilities partially offset
the increased operating income provided by our maintenance and turnaround services. Despite the
increase in the volume of tank construction services provided, contract margins from these services
decreased. Decreased customer spending and increased competitiveness in the tank construction
market in 2010 required that we decrease the margins in our bids in order to remain competitive and
continue winning work. These lower bid margins, combined with losses experienced on several
contracts, resulted in a 7.3 percent decrease in contract margins.
Despite the previously discussed decline in revenue from engineering services, our focus on
cost containment resulted in a $2,553 increase in operating income and a 17.9 percent increase in
operating margin within this business unit. As part of our continuing effort to decrease costs in
this segment and remain competitive in our market, we successfully reduced indirect contract costs
and G&A expenses by $3,182 and $2,847, respectively, compared to the third quarter of 2009.
Included in operating costs for the third quarter of 2010 is $65 in costs associated with headcount
reductions.
During the quarter, the Utility T&D segment generated an operating loss of $16,017, primarily
as a result of the previously mentioned acquisition-related costs charged to this segment. Also
impacting results were lower volumes and a mix shift in transmission construction revenues
associated with the CREZ build out in Texas, resulting in a heavier mix of lower margin work than
anticipated; delayed start up of two significant projects in the northeast (both of which are
currently underway); and in general a weaker market for electric and gas distribution work.
Non-Operating Items
Interest, net expense increased $9,859 (498.7 percent) to $11,836 from $1,977 in 2009. The
increase in net expense is primarily a result of increased interest expense of $8,029 related to
the new Term Loan, debt issuance cost amortization of $978 related to the 2010 Credit Agreement and
a reduction in interest income of $332 due to lower levels of and rates of return on invested cash.
Other, net income increased $857 (680.2 percent) to income of $731 from expense of $126 in
2009. The increase is primarily related to a $385 increase in miscellaneous income in 2010 as
compared to 2009, a reduction in expense of $1,210 related to asset write downs taken in 2009,
offset by a reduction in the gain on sale of fixed assets of $846 in 2010 as compared to 2009.
Provision for income taxes decreased $2,028 to a benefit of $2,687 in 2010 from a benefit of
$659 in 2009. In the third quarter of 2010, total income tax benefit of $2,687 includes a tax
benefit of $4,800 from the impairment of goodwill reduced by a $299 write-off of deferred tax
assets related to tax benefits previously recorded under ASC 718 Stock Compensation that will no
longer be realized and $3,453 of deal costs that received no tax benefit. The $45,340 release of
contingent earnout liability had no tax effect.
Income (loss) from Discontinued Operations, Net of Taxes
Loss from discontinued operations, net of taxes increased $551 (2,040.7 percent) to $578 from
$27 during the same period in 2009. The loss during the three months ended September 30, 2010 is
primarily related to legal fees incurred in connection with the previously discussed WAPCo parent
company guarantee assertions as further discussed in Note 19 Discontinuance of Operations, Asset
Disposals, and Transition Services Agreement. The legal fees are expected to escalate and continue
over the next several years. At this time, we are unable to estimate the likely total costs.
47
Nine Months Ended September 30, 2010 Compared to Nine Months Ended September 30, 2009
Contract Revenue
For the nine months ended September 30, 2010, contract revenue decreased $272,024 (25.5
percent) to $793,917 from $1,065,941 during the same period in 2009. A period-to-period comparison
of revenue is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine months ended September 30, |
|
|
|
|
|
|
|
|
|
|
|
Increase |
|
|
Percent |
|
|
|
2010 |
|
|
2009 |
|
|
(Decrease) |
|
|
Change |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Upstream Oil & Gas |
|
$ |
432,849 |
|
|
$ |
854,066 |
|
|
$ |
(421,217 |
) |
|
|
(49.3 |
)% |
Downstream Oil & Gas |
|
|
202,895 |
|
|
|
211,875 |
|
|
|
(8,980 |
) |
|
|
(4.2 |
)% |
Utility T&D |
|
|
158,173 |
|
|
|
N/A |
|
|
|
158,173 |
|
|
|
100.0 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
793,917 |
|
|
$ |
1,065,941 |
|
|
$ |
(272,024 |
) |
|
|
(25.5 |
)% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Upstream Oil & Gas experienced a significant revenue decrease in the nine months ended
September 30, 2010 as compared to the same period in 2009. We experienced significant revenue
declines in two of the three countries in which we operate, offset by an increase of approximately
10.8 percent in Oman. Lower levels of pipeline construction activity and EPC project activity were
the primary cause of the reduction in revenue.
In the United States, we experienced a revenue decrease of $321,635, or 54.2 percent. This
decline was led by our large-diameter pipeline construction group with a decline of $260,846,
followed by our pipeline facility construction group whose revenue declined $61,856 and our EPC
service line which declined $26,246. These declines were partially offset by growth in revenue from
our specialty services group whose revenue increased $26,156. Our large-diameter pipeline
construction group was fully utilized into the third quarter of 2009 on the Midcontinent Express
Pipeline LLC (MEP) and the Texas Independence Pipeline (TIPS) projects. In 2010, this work was
only partially replaced with our current work on FEP, which began early in the second quarter of
2010. Our specialty service group has grown their revenue by focusing on construction of smaller
diameter and length pipeline construction projects in the Haynesville shale region.
In Canada, we experienced a revenue decrease of $105,023 or 50.1 percent. This decline was
similar to the decline in the United States, led by a decline in our pipeline construction group of
$67,232. This decrease was indicative of the reduced capital budgets associated with the
development of the oil sands in Canada. Our pipeline construction group has three significant
construction projects under contract for this winter construction season. In Oman, we increased
revenue by $5,441, or 10.8 percent, when compared to the same period in 2009. Our business in Oman
is more focused on recurring services for our customers and mitigates the fluctuations of large
capital projects from one period to the next.
Downstream Oil & Gas revenue decreased primarily as a result of a customer rescheduling a
turnaround from the first half of 2010 to the last half of 2010. We were unable to replace this
work during the first half of 2010. A turnaround of similar scope and scale was performed for the
same customer in the first half of 2009. We recognized $28,926 in revenue during the first half of
2009 related to that work. We recognized $8,790 in revenue in the third quarter of 2010 related to
the current year turnaround. Total maintenance and turnaround revenue decreased $9,464 (8.1
percent) year-over-year.
We also experienced a $24,436 (82.2 percent) decrease in revenue from construction services.
While our construction services business unit has maintained a consistent level of consulting
services for our customers long-term capital expansion projects, our involvement in the physical
construction of these projects has decreased from six projects during the first nine months of 2009
to one project in the first nine months of 2010. Our consulting services arrangements were largely
negotiated in prior years for projects that are still ongoing. New capital project activity and
construction opportunities relating to our consulting services have decreased since the latter part
of 2008. This has also affected the volume of work in our fabrication facilities, which
experienced a $9,088 (31.1 percent) decrease in revenue. The level of transfer line replacements
has remained steady compared to the first nine months of 2009; however, the demand for fabrication
of process heaters has decreased as a result of decreased capital spending by our customers.
These declines were partially offset by revenue from the July 2009 acquisition of the Wink
engineering business unit, $19,958, and the reclassification of government services from the
Upstream Oil & Gas segment to the Downstream Oil & Gas segment, $2,345. Additionally, revenue from
tank construction services increased $13,246 (75.5 percent) as a result of several multiple-tank
construction contract awards in the United States and Canada in 2010.
48
Utility T&D, a new segment, contributed revenue of $158,173 as a result of revenues earned
from July 1, 2010 through September 30, 2010 due to the acquisition of InfrastruX.
Operating Income
For the nine months ended September 30, 2010, operating income decreased $53,519 (110.4
percent) to a loss of $5,030 from income of $48,489 during the same period in 2009. A
period-to-period comparison of operating income (loss) is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine months ended September 30, |
|
|
|
|
|
|
|
Operating |
|
|
|
|
|
|
Operating |
|
|
Increase |
|
|
Percent |
|
|
|
2010(1) |
|
|
Margin % |
|
|
2009 |
|
|
Margin % |
|
|
(Decrease) |
|
|
Change |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Upstream Oil & Gas |
|
$ |
37,949 |
|
|
|
8.8 |
% |
|
$ |
46,980 |
|
|
|
5.5 |
% |
|
$ |
(9,031 |
) |
|
|
(19.2 |
)% |
Downstream Oil & Gas |
|
|
(26,962 |
) |
|
|
(13.3 |
)% |
|
|
1,509 |
|
|
|
0.7 |
% |
|
|
(28,471 |
) |
|
|
(1886.7 |
)% |
Utility T&D |
|
|
(16,017 |
) |
|
|
(10.1 |
)% |
|
|
N/A |
|
|
|
N/A |
|
|
|
(16,017 |
) |
|
|
(100.0 |
)% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
(5,030 |
) |
|
|
(0.6 |
)% |
|
$ |
48,489 |
|
|
|
4.5 |
% |
|
$ |
(53,519 |
) |
|
|
(110.4 |
)% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
|
This table does not reflect change in the fair value of contingent
earnout consideration of $45,340 in 2010 which is included in the operating results. The
change in fair value of contingent earnout consideration was characterized as a Corporate
change in estimate and is not allocated to the reporting segments. |
Upstream Oil & Gas operating income decreased as a result of the previously discussed revenue
declines and the significant under utilization of pipeline construction resources in the third
quarter of 2010 as compared to the third quarter of 2009. Contract margins for the Upstream Oil &
Gas segment improved from the prior year, increasing 6.1 percentage points. This increase in
contract margin was partially offset by higher general and administrative costs as a percent of
revenue, increasing from 6.0 percent to 8.9 percent. Our G&A costs were lower than the same period
in 2009, but the drastic reduction of revenue year-over-year negatively impacted our operating
income more than could be recovered by the increased margins.
For our United States operations, our two significant business units performed well in the
challenging economic environment of the first nine months of 2010. Our construction group was able
to increase contract margins while focusing our efforts on FEP and the Haynesville shale play.
However, this margin increase was not enough to offset the impact of the significantly lower
revenue. For our engineering group, the return to profitability in 2010 was highlighted by
contract margins increasing 26.3 percent when compared to the first nine months of 2009. In the
third quarter of 2009 we began to restructure our engineering business to adjust to the current
economic environment, and our 2010 results benefitted from these cost reduction efforts.
In Canada, our operations generated slightly improved contract margins, which increased 0.6
percentage points. However, this slight increase in profitability was not sufficient to offset the
impact of significant reduction in revenue, 50.1 percent, addressed above, leading to lower
operating income from this business unit as our customers capital and maintenance budgets in the
oil sands were reduced from previous levels or deferred to future periods. In Oman, we continue our
consistent performance, with slightly reduced contract margins (0.4 percent) offset by an increase
in revenue of 10.8 percent. We continue to focus on delivering the best value to our clients in a
competitive market for recurring oil field and rig-moving services.
In total, our G&A spend for this segment decreased significantly year-over-year, with business
unit level G&A decreasing $2,184 and corporate allocated G&A decreasing $10,546. These reductions
were the result of cost containment measures implemented across our segment.
Downstream Oil & Gas operating income decreased primarily as a result of the $12,000 goodwill
impairment charge taken in the third quarter of 2010 and the previously discussed decreases in
revenue from maintenance, turnaround, and construction services, as well as operating losses
contributed by the Downstream Oil & Gas engineering business unit ($4,898) and manufacturing
services business unit ($358). Our maintenance and turnaround services business unit contributed an
operating loss in the first nine months of 2010 that was driven largely by a loss on a fixed price
contract and the delay to the third and fourth quarter of a major turnaround originally planned for
execution in the second quarter of 2010.
Additionally, our tank construction and maintenance and turnaround projects realized lower
contract margins in the first nine months of 2010, relative to the first nine months of 2009 due to
pricing pressure from our customers and a more competitive bidding environment. As a result, our
fixed price bids and our rates on cost reimbursable projects subsequently awarded and performed in
the first nine months of 2010 reflected lower margins. These lower bid margins, combined with
losses experienced on several contracts, resulted in contract margin decreases of 12.4 percent on
tank construction services and 2.0 percent on maintenance and turnaround services. Contract
margins for the Downstream Oil & Gas segment decreased 3.1 percent, driven primarily by
these two business units.
49
As part of our continuing effort to decrease costs in this segment and remain competitive in
our market, we successfully reduced indirect contract costs and G&A costs by $11,706 and $4,099,
respectively, compared to the same period for 2009. Included in operating costs for the first nine
months of 2010 is $534 in costs associated with headcount reductions.
During the quarter, the Utility T&D segment generated an operating loss of $16,017, primarily
as a result of the previously mentioned acquisition-related costs charged to this segment. Also
impacting results were lower volumes and a mix shift in transmission construction revenues
associated with the CREZ build out in Texas, resulting in a heavier mix of lower margin work than
anticipated; delayed start up of two significant projects in the northeast (both of which are
currently underway); and in general a weaker market for electric and gas distribution work.
Non-Operating Items
Interest, net expense increased $9,925 (162.9 percent) to $16,018 from $6,093 in 2009. The
increase in net expense is primarily a result of increased interest expense of $8,029 related to
the new Term Loan, debt issuance cost amortization of $978 related to the 2010 Credit Agreement, and
a reduction in interest income of $1,086 due to lower rates of return on invested assets.
Other, net increased $3,611 (20,061.1 percent) to income of $3,593 from expense of $18 in
2009. The 2010 gain is attributed to increased gains on the sale of assets of $784 in 2010 as
compared to 2009, a reduction in expense of $1,210 related to asset write downs taken in 2009, $879
in income recorded in the second quarter of 2010 as a result of a refund of GST based on certain
deductions made in 2010, and a reduction in foreign exchange losses of $243 on U.S. dollar to
Canadian dollar transactions.
Provision for income taxes decreased $18,331 to a benefit of $5,074 in 2010 from tax expense
of $13,257 in 2009. For the first nine months of 2010, tax expense was reduced by $4,800 due to
the goodwill impairment and offset by a $299 write-off of deferred tax assets related to tax
benefits previously recorded under ASC 718 Stock Compensation that will no longer be realized
and $3,453 of deal costs that received no tax benefit. The $45,340 release of contingent earnout
liability had no tax effect.
Income from Discontinued Operations, Net of Taxes
Loss from discontinued operations, net of taxes decreased $203 (13.3 percent) to $1,324 from
$1,527 during the same period in 2009. The decrease is primarily due to a $1,750 charge taken
during the second quarter of 2009 to write-off the net book value of the note related to the
Venezuela sale, as management determined it unlikely to collect due to the nationalization of
various oil contractors within the country. The loss during the nine months ended September 30,
2010 is primarily related to the legal fees incurred in connection with the previously discussed
WAPCo parent company guarantee assertions. The legal fees are expected to escalate and continue
over the next several years. At this time, we are unable to estimate the likely total legal fees.
During the nine months ended September 30, 2010, cash used by operating activities of Discontinued
Operations increased $311 (140.1 percent) to cash used of $533 from $222 cash used during the same
period in 2009.
LIQUIDITY AND CAPITAL RESOURCES
Our financing objective is to maintain financial flexibility to meet the material,
equipment and personnel needs to support our project commitments, pursue our expansion and
diversification objectives, and provide necessary capital to potentially pay off the 6.5% Senior Convertible
Notes (6.5% Notes) on December 15, 2010 and the 2.75% Notes on March 15, 2011. As of September
30, 2010, we had cash and cash equivalents of $100,887. Our cash and cash
equivalent balances held in the United States and foreign countries are $14,725 and $86,162,
respectively.
We are also able to secure funds from a three year revolving credit facility of $175,000 that
was established primarily to provide letters of credit. Through December 31, 2010, we are limited to cash borrowings of $31,500, available only if the 6.5% Notes are put to us for conversion
on December 15, 2010. This amount is approximately equivalent to the face value of the 6.5% Notes.
During the nine months ended September 30, 2010, we decreased our working capital position,
for continuing operations, by $78,241 (26.3 percent) to $219,053 from $297,294 at December 31, 2009
primarily as a result of the movement of $58,006 of our 2.75% Notes to current as the holders of
our 2.75% Notes have the right to require us to purchase the 2.75% Notes for cash, including unpaid
interest, on March 15, 2011. Also contributing to the decrease was a significant reduction in
income from continuing operations due to overall reduction in activity, offset by a decrease in our
receivable days sales outstanding from 91 days at December 31, 2009 to 83 days at September 30,
2010 primarily resulting from various milestone payments received during 2010 along with the
addition of working capital of $77,670 related to our new Utility T&D segment.
Our cash balance has been negatively impacted by two ongoing contract disputes, one with
TransCanada and the other with WAPCo. See Notes 16 and 19 in the accompanying financial statements
for additional background information. As of September 30, 2010, we have $71,159 of unpaid
TransCanada receivables. We
have submitted this dispute to arbitration for resolution; however, final resolution may not
occur for a year or more. We have not established a collectability reserve, and we believe
adequate financial reserves are available during the interim period prior to receiving payment.
The WAPCo claim regarding our performance under a parent company guarantee represents a
likely continuing and escalating legal defense cost for several years.
50
We anticipate that cash on hand, future cash flows from operations, the sale of surplus or
under-utilized equipment, and the availability of our new revolving credit facility will be
sufficient to fund our working capital and capital expenditure objectives for the near term.
Cash Flows
Cash flows provided by (used in) continuing operations by type of activity were as follows for
the nine months ended September 30, 2010 and 2009:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2010 |
|
|
2009 |
|
|
Change |
|
Operating activities |
|
$ |
17,640 |
|
|
$ |
81,230 |
|
|
$ |
(63,590 |
) |
Investing activities |
|
|
(416,085 |
) |
|
|
(16,091 |
) |
|
|
(399,994 |
) |
Financing activities |
|
|
300,311 |
|
|
|
(32,203 |
) |
|
|
332,514 |
|
Effect of exchange rate changes |
|
|
780 |
|
|
|
3,145 |
|
|
|
(2,365 |
) |
|
|
|
|
|
|
|
|
|
|
Cash provided by all continuing activities |
|
$ |
(97,354 |
) |
|
$ |
36,081 |
|
|
$ |
(133,435 |
) |
|
|
|
|
|
|
|
|
|
|
Operating Activities
Operating activities of continuing operations provided $17,640 of cash in the nine months
ended September 30, 2010, compared to cash provided of $81,230 in same period in 2009. Cash
provided by operating activities decreased $63,590 primarily due to:
|
|
|
an increase in the cash consumed by continuing operations of $32,241, net of non-cash
effects; offset by |
|
|
|
a decrease in cash flow from working capital of $31,349, driven primarily by the
$117,636 increase in accounts receivable as a result of an increase in days sales
outstanding from 66 in the third quarter of 2009 to 83 in the third quarter of 2010
resulting from the ongoing contract dispute with TransCanada; offset by net changes in
other working capital accounts of $86,287 driven primarily by the reduction in contract
volume year over year. |
Investing Activities
Investing activities of continuing operations used $416,085 of cash in the nine months ended
September 30, 2010, compared to a use of cash of $16,091 during the same period in 2009. Cash used
by investing activities increased $399,994 primarily due to:
|
|
|
the acquisition of InfrastruX, which resulted in an increase in cash used of $407,227;
offset by; |
|
|
|
an increase in net maturities of short-term investments of $16,500. |
Financing Activities
Financing activities of continuing operations provided $300,311 of cash in the nine months
ended September 30, 2010, compared to a use of $32,203 in the same period of 2009. Cash provided by
financing activities increased $332,514 primarily due to:
|
|
|
the $282,000 net proceeds after the $18,000 original issue discount provided from the
Term Loan issued in connection with funding of the InfrastruX acquisition; and |
|
|
|
the proceeds received of $58,078 from the issuance of common stock which was used to
fund the purchase of InfrastruX; offset by additional debt issuance costs of $16,384 for
the new 2010 Credit Facility and Term Loan completed concurrently with our acquisition of
InfrastruX. |
Revolving Credit Facility
We
entered into the 2010 Credit Agreement dated June 30, 2010, that
consists of a four year, $300,000 Term Loan maturing in July 2014 and a
three year revolving credit facility of $175,000, maturing in July 2013
and replacing our existing three-year $150,000 senior secured credit facility, which was
scheduled to expire in November 2010. The proceeds from the Term Loan were used to pay part of the
cash portion of the merger consideration payable in connection with
our acquisition of
InfrastruX.
51
Interest Rate Risk
We are subject to hedging arrangements to fix or otherwise limit the interest cost of the term
loans. We are subject to interest rate risk on our debt and investment of cash and cash
equivalents arising in the normal course of business, as we do not engage in speculative trading
strategies.
In
September 2010, we entered into two 18month forward
interest rate swap agreements for a total notional amount of
$150,000 in order to hedge changes in the variable rate interest expense of half of the $300,000
Term Loan maturing on June 30, 2014. Under the swap agreement, we receive interest at a
floating rate of three-month Libor, conditional on three-month Libor exceeding 2 percent (to mirror
variable rate interest provisions of the underlying hedged debt), and pays interest at a fixed rate
of 2.685 percent, effective March 28, 2012 through June 30, 2014. The swap agreement is designated
and qualifies as a cash flow hedging instrument, with the effective portion of the swaps change in
fair value recorded in Other Comprehensive Income (OCI). The swap of the variable rate interest is
deemed to be a highly effective hedge, and resulted in no gain or loss recorded for hedge
ineffectiveness in the consolidated condensed statement of income. Amounts in OCI are
reported in interest expense when the hedged interest payments on the underlying debt are
recognized. The fair value of the swap agreement was determined using a model with observable
inputs (Level 2) including quoted market prices for contracts with similar terms and maturity
dates.
Also in September 2010, we entered into two interest rate cap agreements for notional amounts
of $75,000 each in order to limit the Term Loans interest rates exposure to an increase of the
interest rate above 3 percent, effective September 28, 2010 through March 28, 2012. Total premiums
of $98 were paid for the interest rate caps. The cap agreements are designated and qualify as
cash flow hedging instruments, with the effective portion of the caps change in fair value
recorded in OCI. Amounts in OCI and the premiums paid for the caps are reported in interest
expense as the hedged interest payments on the underlying debt are recognized. The interest rate
caps are deemed to be highly effective, resulting in an immaterial amount of hedge ineffectiveness
recorded in the consolidated condensed statement of income. The fair value of the Interest
Rate Cap Agreements was determined using a model with Level 2 inputs including quoted market prices
for contracts with similar terms and maturity dates. An immaterial amount of OCI relating to the
interest rate swap and caps is expected to be recognized in earnings in the coming 12 months.
Capital Requirements
During the nine months ended September 30, 2010, continuing operations provided cash of
$17,640. We believe that our financial results combined with our current liquidity, financial
management, the new Term Loan and the 2010 Credit Facility previously discussed will ensure
sufficient cash to meet our capital requirements for continuing operations. As such, we are focused
on the following significant capital requirements:
|
|
|
Providing working capital for projects in process and those scheduled to begin; |
|
|
|
Funding the committed portion of our 2010 capital budget of approximately $5,742; |
|
|
|
Making installment payments to the government related to fines and profit disgorgement;
and |
|
|
|
Redeeming up to $32,050 of our 6.5% Notes and up to $59,357 of our 2.75% Notes if all of
the note holders elect to exercise their right to require us to purchase the notes on
December 15, 2010 and March 15, 2011, respectively. |
We believe that we will be able to support our ongoing working capital needs through our cash
on hand, operating cash flows, sales of idle and under-utilized equipment and potentially, the
previously discussed new Term Loan and 2010 Credit Facility.
Contractual Obligations
As of September 30, 2010, we had aggregate convertible note principal outstanding of $91,407.
In addition, we have various capital leases of construction equipment and property resulting in
aggregate capital lease obligations of $15,975 at September 30, 2010. The holders of our 2.75%
Notes have the right to require us to purchase the 2.75% Notes for cash, including unpaid interest,
on March 15, 2011. Based on the uncertainty surrounding the future economic conditions, we were
unable to estimate the number or probability of future repurchases of the 2.75% Notes on March 15,
2011. As such, all $58,006 (net of $1,351 bond discount) has been classified as short-term and
included within Notes payable and current portion of other long-term debt on the Consolidated
Balance Sheet at September 30, 2010. As of December 31, 2009, we previously reclassified $31,450
(net of $600 bond discount) of 6.5% Notes as a current liability for similar reasons. The holders
of the 6.5% Notes have the right to require us to purchase the notes for cash, including unpaid
interest, on December 15, 2010.
At September 30, 2010, we had uncertain tax positions which ultimately could result in a tax
payment. As the amount of the ultimate tax payment is contingent on the tax authorities
assessment, it is not practical to present annual payment information.
52
As of September 30, 2010, there were no borrowings under 2010 Credit Agreement revolving
credit facility and there were $9,689 in outstanding letters of credit. All outstanding letters of
credit related to continuing operations.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Payments Due By Period |
|
|
|
|
|
|
2010 to |
|
|
2012 to |
|
|
2014 to |
|
|
More than |
|
|
|
Total |
|
|
2011 |
|
|
2013 |
|
|
2015 |
|
|
5 years |
|
Term Loan |
|
$ |
300,000 |
|
|
$ |
15,750 |
|
|
$ |
30,000 |
|
|
$ |
254,250 |
|
|
$ |
|
|
Convertible notes |
|
|
91,407 |
|
|
|
91,407 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Capital lease obligations |
|
|
17,108 |
|
|
|
9,548 |
|
|
|
7,511 |
|
|
|
49 |
|
|
|
|
|
Operating lease obligations |
|
|
74,358 |
|
|
|
26,346 |
|
|
|
24,177 |
|
|
|
11,890 |
|
|
|
11,945 |
|
Equipment financing obligations |
|
|
2,467 |
|
|
|
1,692 |
|
|
|
775 |
|
|
|
|
|
|
|
|
|
Contingent earnout |
|
|
10,000 |
|
|
|
10,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Uncertain tax liabilities |
|
|
4,510 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
499,850 |
|
|
$ |
154,743 |
|
|
$ |
62,463 |
|
|
$ |
266,189 |
|
|
$ |
11,945 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other commercial commitments, as detailed in our annual report on Form 10-K for the year ended
December 31, 2009, did not materially change except for payments made in the normal course of
business.
NEW ACCOUNTING PRONOUNCEMENTS
See Note 2 New Accounting Pronouncements in the Notes to the Condensed Consolidated
Financial Statements included in this Form 10-Q for a summary of any recently issued accounting
standards.
53
FORWARD-LOOKING STATEMENTS
This Form 10-Q includes forward-looking statements. All statements, other than statements of
historical facts, included in this Form 10-Q that address activities, events or developments which
we expect or anticipate will or may occur in the future, including such things as future capital
expenditures (including the amount and nature thereof), oil, gas, gas liquids and power prices,
demand for our services, the amount and nature of future investments by governments, expansion and
other development trends of the oil and gas, refinery, petrochemical and power industries, business
strategy, expansion and growth of our business and operations, the outcome of government
investigations and legal proceedings and other such matters are forward-looking statements. These
forward-looking statements are based on assumptions and analyses we made in light of our experience
and our perception of historical trends, current conditions and expected future developments as
well as other factors we believe are appropriate under the circumstances. However, whether actual
results and developments will conform to our expectations and predictions is subject to a number of
risks and uncertainties. As a result, actual results could differ materially from our expectations.
Factors that could cause actual results to differ from those contemplated by our forward-looking
statements include, but are not limited to, the following:
|
|
|
curtailment of capital expenditures and the unavailability of project funding in the oil
and gas, refinery, petrochemical and power industries; |
|
|
|
increased capacity and decreased demand for our services in the more competitive
industry segments that we serve; |
|
|
|
reduced creditworthiness of our customer base and higher risk of non-payment of
receivables; |
|
|
|
inability to lower our cost structure to remain competitive in the market; |
|
|
|
inability of the energy service sector to reduce costs in the short term to a level
where our customers project economics support a reasonable level of development work; |
|
|
|
inability to predict the timing of an increase in energy sector capital spending, which
results in staffing below the level required when the market recovers; |
|
|
|
reduction of services to existing and prospective clients as they bring historically
out-sourced services back in-house to preserve intellectual capital and minimize layoffs; |
|
|
|
the consequences we may encounter if we fail to comply with the terms and conditions of
our final settlements with the Department of Justice (DOJ) and the Securities and
Exchange Commission (SEC), including the imposition of civil or criminal fines,
penalties, enhanced monitoring arrangements, or other sanctions that might be imposed by
the DOJ and SEC; |
|
|
|
the issues we may encounter with respect to the federal monitor appointed under our
Deferred Prosecution Agreement with the DOJ and any changes in our business practices which
the monitor may require; |
|
|
|
the commencement by foreign governmental authorities of investigations into the actions
of our current and former employees, and the determination that such actions constituted
violations of foreign law; |
|
|
|
difficulties we may encounter in connection with the previous sale and disposition of
our Nigeria assets and Nigeria based operations, including obtaining indemnification for
any losses we may experience if, due to the non-performance by the purchaser of these
assets, claims are made against any parent company guarantees we provided, to the extent
those guarantees may be determined to have continued validity; |
|
|
|
the dishonesty of employees and/or other representatives or their refusal to abide by
applicable laws and our established policies and rules; |
|
|
|
adverse weather conditions not anticipated in bids and estimates; |
|
|
|
project cost overruns, unforeseen schedule delays and the application of liquidated
damages; |
|
|
|
the occurrence during the course of our operations of accidents and injuries to our
personnel, as well as to third parties, that negatively affect our safety record, which is
a factor used by many clients to pre-qualify and otherwise award work to contractors in our
industry; |
|
|
|
cancellation of projects, in whole or in part, for any reason; |
|
|
|
failing to realize cost recoveries on claims or change orders from projects completed or
in progress within a reasonable period after completion of the relevant project; |
54
|
|
|
political or social circumstances impeding the progress of our work and increasing the
cost of performance; |
|
|
|
inability to obtain and maintain legal registration status in one or more foreign
countries in which we are seeking to do business; |
|
|
|
failure to obtain the timely award of one or more projects; |
|
|
|
inability to identify and acquire suitable acquisition targets or to finance such
acquisitions on reasonable terms; |
|
|
|
inability to hire and retain sufficient skilled labor to execute our current work, our
work in backlog and future work we have not yet been awarded; |
|
|
|
inability to execute cost-reimbursable projects within the target cost, thus eroding
contract margin and, potentially, contract income on any such project; |
|
|
|
inability to obtain sufficient surety bonds or letters of credit; |
|
|
|
inability to obtain adequate financing; |
|
|
|
loss of the services of key management personnel; |
|
|
|
the demand for energy moderating or diminishing; |
|
|
|
downturns in general economic, market or business conditions in our target markets; |
|
|
|
changes in and interpretation of U.S. and foreign tax laws that impact our worldwide
provision for income taxes and effective income tax rate; |
|
|
|
the potential adverse effects on our operating results if our non-U.S. operations became
taxable in the United States; |
|
|
|
changes in applicable laws or regulations, or changed interpretations thereof, including
climate change legislation; |
|
|
|
changes in the scope of our expected insurance coverage; |
|
|
|
inability to manage insurable risk at an affordable cost; |
|
|
|
enforceable claims for which we are not fully insured; |
|
|
|
incurrence of insurable claims in excess of our insurance coverage; |
|
|
|
the occurrence of the risk factors listed elsewhere in this Form 10-Q or described in
our periodic filings with the SEC; and |
|
|
|
other factors, most of which are beyond our control. |
Consequently, all of the forward-looking statements made in this Quarterly Report on Form 10-Q
are qualified by these cautionary statements and there can be no assurance that the actual results
or developments we anticipate will be realized or, even if substantially realized, that they will
have the consequences for, or effects on, our business or operations that we anticipate today. We
assume no obligation to update publicly any such forward-looking statements, whether as a result of
new information, future events or otherwise.
Unless the context otherwise requires, all references in this Quarterly Report on Form 10-Q to
Willbros, the Company, we, us and our refer to Willbros Group, Inc., its consolidated
subsidiaries and their predecessors. Unless the context otherwise requires, all references in this
Quarterly Report on Form 10-Q to dollar amounts, except share and per share amounts, are expressed
in thousands.
55
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Our primary market risk is our exposure to changes in non-U.S. currency exchange rates. We
attempt to negotiate contracts which provide for payment in U.S. dollars, but we may be required to
take all or a portion of payment under a contract in another currency. To mitigate non-U.S.
currency exchange risk, we seek to match anticipated non-U.S. currency revenue with expenses in the
same currency whenever possible. To the extent, we are unable to match non-U.S. currency revenue
with expenses in the same currency, we may use forward contracts, options or other common hedging
techniques in the same non-U.S. currencies. We had no forward contracts or options at September 30,
2010 and 2009 or during the three months then ended.
The carrying amounts for cash and cash equivalents, accounts receivable, notes payable and
accounts payable, and accrued liabilities shown in the Condensed Consolidated Balance Sheet
approximated fair value at September 30, 2010, due to the generally short maturities of these
items. At September 30, 2010, our investments were primarily in short-term dollar denominated bank
deposits with maturities of a few days, or in longer-term deposits where funds can be withdrawn on
demand without penalty. We have the ability and expect to hold our investments to maturity.
In conjunction with the 2010 Credit Agreement we entered into as of June 30, 2010, we are
subject to hedging arrangements to fix or otherwise limit the interest cost of the term loan.
Therefore, as of September 30, 2010, we entered into two
18month forward interest rate swap agreements for a total notional amount of
$150,000 in order to hedge changes in the variable rate interest expense of half of the $300,000
Term Loan maturing on June 30, 2014. Under the swap agreement, we receive interest at a
floating rate of three-month LIBOR, conditional on three-month LIBOR exceeding 2 percent (to mirror
variable rate interest provisions of the underlying hedged debt), and pays interest at a fixed rate
of 2.685 percent, effective March 28, 2012 through June 30, 2014. The swap agreement is designated
and qualifies as a cash flow hedging instrument and is deemed to be a highly effective hedge. The
fair value of the swap agreement at September 30, 2010 was $711 and was based on using a model with
Level 2 inputs including quoted market prices for contracts with similar terms and maturity dates.
We also entered into two interest rate cap agreements for notional amounts of $75,000 each in
order to limit exposure to an increase of the interest rate above 3 percent, effective September
28, 2010 through March 28, 2012. The cap agreements are designated and qualify as cash flow hedging
instruments and are deemed to be highly effective hedges. The fair value of the interest rate caps
was $3 and was based on using a model with Level 2 inputs including quoted market prices for
contracts with similar terms and maturity dates.
ITEM 4. CONTROLS AND PROCEDURES
In connection with the preparation of this Quarterly Report on Form 10-Q for the quarter ended
September 30, 2010 we have carried out an evaluation under the supervision of, and with the
participation of, our management, including the Chief Executive Officer and Chief Financial
Officer, of the effectiveness of the design and operation of our disclosure controls and procedures
(as such term is defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act). There are
inherent limitations to the effectiveness of any system of disclosure controls and procedures,
including the possibility of human error and the circumvention or overriding of the controls and
procedures. Accordingly, even effective disclosure controls and procedures can only provide
reasonable assurance of achieving their control objectives. Based on this evaluation, our Chief
Executive Officer and Chief Financial Officer have concluded that the disclosure controls and
procedures were effective as of September 30, 2010 to (1) provide reasonable assurance that
information required to be disclosed in reports that we file or submit under the Exchange Act is
recorded, processed, summarized and reported within the time periods specified in SEC rules and
forms and (2) provide reasonable assurance that information required to be disclosed in the reports
that we file or submit under the Exchange Act is accumulated and communicated to our management,
including the principal executive officer and principal financial officer, as appropriate to allow
timely decisions regarding required disclosure.
On July 1, 2010, the Company closed on the acquisition of InfrastruX Group, Inc. The Company
is in the process of assessing and, to the extent necessary, making changes to the internal control
over financial reporting to conform such Internal control to that used in the Companys other
segments. Based on the information presently available to management, the Company does not believe
such changes will adversely impact the Companys internal control over financial reporting. Subject
to the foregoing, there were no changes in our internal control over financial reporting that
materially affected, or are reasonably likely to materially affect, our internal control over
financial reporting during the quarter ended September 30, 2010.
56
PART II. OTHER INFORMATION
Item 1. Legal Proceedings
For information regarding legal proceedings, see the discussion under the captions Contingencies
Facility Construction Project Termination in Note 16 Contingencies, Commitments and Other
Circumstances and Nigeria Assets and Nigeria-Based Operations Share Purchase Agreement in Note
19 Discontinuance of Operations, Asset Disposals, and Transition Services Agreement of our Notes
to Condensed Consolidated Financial Statements in Item 1 of Part I of this Form 10-Q, which
information from Notes 16 and 19 is incorporated by reference herein.
Item 1A. Risk Factors
Except as set forth below, there have been no material changes to the risk factors involving us
from those previously disclosed in Item 1A of Part II in our Quarterly Report on Form 10-Q for the
quarter ended June 30, 2010.
We provided an updated set of risk factors in our Quarterly
Report on Form 10- Q for the quarter ended June 30, 2010, which superseded the risk factors included in our Annual Report on Form
10-K for the year ended December 31, 2009, our Quarterly Report on Form 10-Q for the quarter ended
March 31, 2010 and our Current Report on Form 8-K dated May 17, 2010, filed May 20, 2010.
Our failure to resolve matters related to a facility construction project termination could have a
material adverse impact on us.
On January 13, 2010, TransCanada Pipelines, Ltd. (TCPL) notified us that we were in breach of
contract and were being terminated for cause immediately on a facility construction contract for
seven pump stations in Nebraska and Kansas that was awarded to us in September 2008. At the time of
termination, we had completed approximately 91.0 percent of our scope of work.
We have disputed the validity of the termination for cause and have challenged the contractual
procedure followed by TCPL for termination for cause, which allows for a 30-day notification period
during which time we are supposed to have an opportunity to remedy the alleged default.
Subsequently, we agreed in good faith to cooperate with TCPL in an orderly demobilization and
handover of the remaining work. As of September 30, 2010, we have outstanding receivables related
to this project of $71.2 million and unapproved change orders for additional work of $3.7 million
which have not been billed. Additionally, there are claims for additional fee totaling $16.7
million for additional work. It is our policy not to recognize revenue or income on unapproved
change orders or claims until they have been approved. Accordingly, the $3.7 million in pending
change orders and the $16.7 million of claims have been excluded from our revenue recognition.
If the termination for cause is determined to be valid and enforceable, we could be held liable for
any damages resulting from the alleged breach of contract, including but not limited to costs
incurred by TCPL to hire a replacement contractor to complete the estimated 9.0 percent remainder
of the work less the cost that we would have incurred to perform the same scope of work. Although
we do not believe we are in breach of contract and intend to pursue our contractual and legal
remedies, including having commenced arbitration and filed liens on constructed facilities, the
resolution of this matter could have a material adverse effect on our financial condition or
results of operations. TCPL response to the notice of arbitration included a counterclaim for
damages of $23.0 million for the alleged breach of contract. TCPL has also disclaimed
responsibility for payment of the current receivable balance outstanding at September 30, 2010, the
unapproved change orders, and claims for additional work. TransCanada has removed us from
TransCanadas bid list.
Our goodwill may become impaired.
We have a substantial amount of goodwill following our acquisitions of InfrastruX, Integrated
Service Company, Midwest Management (1987) Ltd. and Wink Companies, LLC. At least annually, we
evaluate our goodwill for impairment based on the fair value of each operating unit. This estimated
fair value could change if there were future changes in our capital structure, cost of debt,
interest rates, capital expenditure levels or ability to perform at levels that were forecasted.
These changes could result in an impairment that would require a material non-cash charge to our
results of operations. A significant decrease in expected cash flows or changes in market
conditions may indicate potential impairment of recorded goodwill. During the third quarter of 2010, in connection with the completion of the
preliminary forecast for 2011, it became evident that a goodwill impairment at Downstream Oil & Gas
was probable. As a result, a preliminary step one analysis for that segment was performed. Using
a discounted cash flow analysis supported by comparative market multiples to determine the fair
value of the segment versus its carrying value, a range of likely impairment was generated. The
low end of this range was approximately $12,000. Accordingly, we have
recoded an impairment charge of $12,000 during the third quarter of 2010.
57
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
The following table provides information about purchases of our common stock by us during the
quarter ended September 30, 2010:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
|
Maximum |
|
|
|
|
|
|
|
|
|
|
|
Number of |
|
|
Number (or |
|
|
|
|
|
|
|
|
|
|
|
Shares |
|
|
Approximate |
|
|
|
|
|
|
|
|
|
|
|
Purchased |
|
|
Dollar Value) of |
|
|
|
|
|
|
|
|
|
|
|
as Part of |
|
|
Shares That May |
|
|
|
Total |
|
|
|
|
|
|
Publicly |
|
|
Yet Be |
|
|
|
Number of |
|
|
Average |
|
|
Announced |
|
|
Purchased |
|
|
|
Shares |
|
|
Price Paid Per |
|
|
Plans or |
|
|
Under the Plans |
|
|
|
Purchased (1) |
|
|
Share (2) |
|
|
Programs |
|
|
or Programs |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
July 1, 2010 July 31, 2010 |
|
|
14,013 |
|
|
$ |
8.82 |
|
|
|
|
|
|
|
|
|
August 1, 2010 August 31, 2010 |
|
|
12,830 |
|
|
|
7.93 |
|
|
|
|
|
|
|
|
|
September 1, 2010 September 30, 2010 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
|
26,843 |
|
|
$ |
8.40 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
|
Shares of common stock acquired from certain of our officers and key employees
under the share withholding provisions of our 1996 Stock Plan for the payment of taxes
associated with the vesting of shares of restricted stock granted under such plan. |
|
(2) |
|
The price paid per common share represents the closing sales price of a share of our
common stock, as reported in the New York Stock Exchange composite transactions, on the day
that the stock was acquired by us. |
Item 3. Defaults upon Senior Securities
Not applicable.
Item 4. Reserved
Item 5. Other Information
Not applicable.
58
Item 6. Exhibits
The following documents are included as exhibits to this Form 10-Q. Those exhibits below
incorporated by reference herein are indicated as such by the information supplied in the
parenthetical thereafter. If no parenthetical appears after an exhibit, such exhibit is filed
herewith.
|
|
|
|
|
|
10.1 |
|
|
Employment Agreement dated May 8, 2006, between InfrastruX Group, Inc. and Michael T.
Lennon and Amendment thereto dated December 31, 2008. |
|
|
|
|
|
|
10.2 |
|
|
Employment Agreement dated as of September 20, 2010, between Willbros United States
Holdings, Inc. and Robert R. Harl (filed as Exhibit 10.1 to our report on Form 8-K dated
September 20, 2010, filed September 22, 2010). |
|
|
|
|
|
|
10.3 |
|
|
Bonus Agreement dated as of September 20, 2010, between Willbros United States
Holdings, Inc. and Robert R. Harl (filed as Exhibit 10.2 to our report on Form 8-K dated
September 20, 2010, filed September 22, 2010). |
|
|
|
|
|
|
10.4 |
|
|
Amendment Number 3 to Willbros Group, Inc. Amended and Restated 2006 Director
Restricted Stock Plan dated August 25, 2010. |
|
|
|
|
|
|
31.1 |
|
|
Certification of Chief Executive Officer pursuant to Rule 13a-14(a) of the Securities
Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. |
|
|
|
|
|
|
31.2 |
|
|
Certification of Chief Financial Officer pursuant to Rule 13a-14(a) of the Securities
Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. |
|
|
|
|
|
|
32.1 |
|
|
Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as
adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. |
|
|
|
|
|
|
32.2 |
|
|
Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as
adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. |
59
SIGNATURE
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.
|
|
|
|
|
|
WILLBROS GROUP, INC.
|
|
Date: November 8, 2010 |
By: |
/s/ Van A. Welch
|
|
|
|
Van A. Welch |
|
|
|
Senior Vice President and Chief Financial
Officer (Principal Financial Officer and
Principal Accounting Officer) |
|
|
60
EXHIBIT INDEX
The following documents are included as exhibits to this Form 10-Q. Those exhibits below
incorporated by reference herein are indicated as such by the information supplied in the
parenthetical thereafter. If no parenthetical appears after an exhibit, such exhibit is filed
herewith.
|
|
|
|
|
Exhibit |
|
|
Number |
|
Description |
|
|
|
|
|
|
10.1 |
|
|
Employment Agreement dated May 8, 2006, between InfrastruX Group, Inc. and Michael T.
Lennon and Amendment thereto dated December 31, 2008. |
|
|
|
|
|
|
10.2 |
|
|
Employment Agreement dated as of September 20, 2010, between Willbros United States
Holdings, Inc. and Robert R. Harl (filed as Exhibit 10.1 to our report on Form 8-K dated
September 20, 2010, filed September 22, 2010). |
|
|
|
|
|
|
10.3 |
|
|
Bonus Agreement dated as of September 20, 2010, between Willbros United States
Holdings, Inc. and Robert R. Harl (filed as Exhibit 10.2 to our report on Form 8-K dated
September 20, 2010, filed September 22, 2010). |
|
|
|
|
|
|
10.4 |
|
|
Amendment Number 3 to Willbros Group, Inc. Amended and Restated 2006 Director
Restricted Stock Plan dated August 25, 2010. |
|
|
|
|
|
|
31.1 |
|
|
Certification of Chief Executive Officer pursuant to Rule 13a-14(a) of the Securities
Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. |
|
|
|
|
|
|
31.2 |
|
|
Certification of Chief Financial Officer pursuant to Rule 13a-14(a) of the Securities
Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. |
|
|
|
|
|
|
32.1 |
|
|
Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as
adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. |
|
|
|
|
|
|
32.2 |
|
|
Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as
adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. |
61