Layne Christensen Company 10-Q
FORM 10-Q
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
(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 April 30, 2008
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 0-20578
Layne Christensen Company
(Exact name of registrant as specified in its charter)
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Delaware
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48-0920712 |
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State or other jurisdiction of
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(I.R.S. Employer Identification No.) |
incorporation or organization) |
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1900 Shawnee Mission Parkway, Mission Woods, Kansas
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66205 |
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(Address of principal executive offices)
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(Zip Code) |
(Registrants telephone number, including area code) (913) 362-0510
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 is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See the definitions of large accelerated filer, accelerated filer and smaller reporting company in Rule 12b-2 of the Exchange Act. (Check one):
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Large accelerated filer o
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Accelerated filer þ
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Non-accelerated filer o
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Smaller reporting company o |
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(Do not check if a smaller reporting company) |
Indicate by check mark whether the Registrant is a shell company (as defined in Rule 12b-2 of the
Exchange Act).
Yes o No þ
There were 19,231,950 shares of common stock, $.01 par value per share, outstanding on May 19,
2008.
TABLE OF CONTENTS
PART I
Item 1. Financial Statements
LAYNE CHRISTENSEN COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(in thousands)
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April 30, |
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January 31, |
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2008 |
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2008 |
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(unaudited) |
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(unaudited) |
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ASSETS |
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Current assets: |
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Cash and cash equivalents |
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$ |
53,167 |
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$ |
73,068 |
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Customer receivables, less allowance of
$7,570 and $7,571, respectively |
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133,639 |
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125,091 |
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Costs and estimated earnings in excess of billings on
uncompleted contracts |
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73,432 |
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60,796 |
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Inventories |
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24,134 |
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21,020 |
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Deferred income taxes |
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18,830 |
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18,711 |
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Income taxes receivable |
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866 |
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866 |
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Restricted cash-current |
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500 |
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500 |
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Other |
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4,731 |
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5,288 |
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Total current assets |
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309,299 |
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305,340 |
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Property and equipment: |
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Land |
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8,659 |
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8,643 |
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Buildings |
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22,145 |
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21,868 |
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Machinery and equipment |
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307,592 |
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299,642 |
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Gas transportation facilities and equipment |
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31,879 |
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30,266 |
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Oil and gas properties |
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80,482 |
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76,844 |
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Mineral interests in oil and gas properties |
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19,744 |
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18,165 |
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Less Accumulated depreciation and depletion |
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(219,422 |
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(208,061 |
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Net property and equipment |
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251,079 |
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247,367 |
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Other assets: |
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Investment in affiliates |
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32,054 |
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29,835 |
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Goodwill |
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85,706 |
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85,706 |
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Other intangible assets, net |
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20,627 |
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20,930 |
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Restricted cash-long term |
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1,185 |
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505 |
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Other |
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8,148 |
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7,272 |
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Total other assets |
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147,720 |
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144,248 |
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$ |
708,098 |
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$ |
696,955 |
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See Notes to Consolidated Financial Statements.
Continued
2
LAYNE CHRISTENSEN COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS (Continued)
(in thousands, except per share data)
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April 30, |
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January 31, |
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2008 |
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2008 |
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(unaudited) |
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(unaudited) |
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LIABILITIES AND STOCKHOLDERS EQUITY |
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Current liabilities: |
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Accounts payable |
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$ |
64,892 |
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$ |
67,777 |
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Current maturities of long term debt |
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13,333 |
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13,333 |
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Accrued compensation |
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26,590 |
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36,763 |
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Accrued insurance expense |
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8,872 |
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8,158 |
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Other accrued expenses |
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17,598 |
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15,222 |
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Acquisition escrow obligation-current |
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550 |
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550 |
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Income taxes payable |
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10,070 |
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4,200 |
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Billings in excess of costs and estimated
earnings on uncompleted contracts |
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33,349 |
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31,641 |
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Total current liabilities |
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175,254 |
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177,644 |
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Noncurrent and deferred liabilities: |
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Long-term debt |
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46,667 |
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46,667 |
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Accrued insurance expense |
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9,032 |
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9,736 |
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Deferred income taxes |
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29,069 |
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28,329 |
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Acquisition escrow obligation-long term |
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1,185 |
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505 |
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Minority interest |
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398 |
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398 |
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Other |
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10,653 |
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10,304 |
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Total noncurrent and deferred liabilities |
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97,004 |
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95,939 |
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Common stock, par value
$.01 per share, 30,000 shares authorized, 19,210 and 19,161
shares issued and outstanding, respectively |
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192 |
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192 |
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Capital in excess of par value |
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329,789 |
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328,301 |
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Retained earnings |
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112,385 |
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101,866 |
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Accumulated other comprehensive loss |
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(6,526 |
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(6,987 |
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Total stockholders equity |
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435,840 |
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423,372 |
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$ |
708,098 |
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$ |
696,955 |
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See Notes to Consolidated Financial Statements.
3
LAYNE CHRISTENSEN COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
(in thousands, except per share data)
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Three Months |
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Ended April 30, |
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(unaudited) |
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2008 |
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2007 |
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Revenues |
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$ |
244,544 |
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$ |
201,615 |
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Cost of revenues
(exclusive of depreciation, depletion and amortization shown below) |
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182,040 |
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147,318 |
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Selling, general and administrative expenses |
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33,044 |
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29,408 |
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Depreciation, depletion and amortization |
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12,441 |
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10,338 |
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Other income (expense): |
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Equity in earnings of affiliates |
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2,497 |
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1,491 |
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Interest |
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(941 |
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(2,430 |
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Other income, net |
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(46 |
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207 |
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Income before income taxes |
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18,529 |
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13,819 |
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Income tax expense |
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7,967 |
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5,666 |
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Net income |
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$ |
10,562 |
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$ |
8,153 |
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Basic income per share |
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$ |
0.55 |
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$ |
0.53 |
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Diluted income per share |
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$ |
0.55 |
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$ |
0.52 |
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Basic weighted average shares outstanding |
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19,091 |
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15,517 |
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Dilutive stock options |
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203 |
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235 |
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Diluted weighted average shares outstanding |
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19,294 |
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15,752 |
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See Notes to Consolidated Financial Statements.
4
LAYNE CHRISTENSEN COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOW
(in thousands)
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Three Months |
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Ended April 30, |
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(unaudited) |
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2008 |
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2007 |
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Cash flow from operating activities: |
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Net income |
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$ |
10,562 |
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$ |
8,153 |
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Adjustments to reconcile net income to cash from operations: |
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Depreciation, depletion and amortization |
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12,441 |
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10,338 |
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Deferred income taxes |
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621 |
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(359 |
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Share-based compensation |
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1,086 |
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511 |
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Income tax benefit from share-based compensation |
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(58 |
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Equity in earnings of affiliates |
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(2,497 |
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(1,491 |
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Dividends received from affiliates |
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278 |
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522 |
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Gain (loss) from disposal of property and equipment |
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236 |
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(18 |
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Changes in current assets and liabilities,
net of effects of acquisitions: |
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Increase in customer receivables |
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(8,548 |
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(6,996 |
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Increase in costs and estimated earnings in
excess
of billings on uncompleted contracts |
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(12,636 |
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(8,412 |
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Increase in inventories |
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(3,114 |
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(1,208 |
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Decrease in other current assets |
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557 |
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2,759 |
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(Decrease) increase in accounts payable and accrued expenses |
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(3,146 |
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7,255 |
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Increase (decrease) in billings in excess of costs and
estimated earnings on uncompleted contracts |
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1,708 |
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(1,332 |
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Other, net |
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(1,500 |
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(1,210 |
) |
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Cash (used in) provided by operating activities |
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(4,010 |
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8,512 |
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Cash flow from investing activities: |
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Additions to property and equipment |
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(9,082 |
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(7,779 |
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Additions to gas transportation facilities and equipment |
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(1,613 |
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(713 |
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Additions to oil and gas properties |
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(3,637 |
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(2,540 |
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Additions to mineral interests in oil and gas properties |
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(1,578 |
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(1,584 |
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Proceeds from disposal of property |
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426 |
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99 |
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Deposit of cash into restricted accounts |
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(680 |
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Cash used in investing activities |
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(16,164 |
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(12,517 |
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Cash flow from financing activities: |
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Borrowings under revolving credit facility |
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111,200 |
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Repayments under revolving credit facility |
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(100,400 |
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Excess tax benefit on exercise of share-based instruments |
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58 |
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Issuance of common stock upon exercise of stock options |
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339 |
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Cash provided by financing activities |
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397 |
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10,800 |
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Effects of exchange rate changes on cash |
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(124 |
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(58 |
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Net (decrease) increase in cash and cash equivalents |
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(19,901 |
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6,737 |
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Cash and cash equivalents at beginning of period |
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73,068 |
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13,007 |
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Cash and cash equivalents at end of period |
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$ |
53,167 |
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$ |
19,744 |
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See Notes to Consolidated Financial Statements.
5
LAYNE CHRISTENSEN COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. Accounting Policies and Basis of Presentation
Principles of Consolidation The consolidated financial statements include the accounts of Layne
Christensen Company and its subsidiaries (together, the Company). All significant intercompany
transactions have been eliminated. Investments in affiliates (20% to 50% owned) in which the
Company exercises influence over operating and financial policies are accounted for by the equity
method. The unaudited consolidated financial statements should be read in conjunction with the
consolidated financial statements of the Company for the year ended January 31, 2008 as filed in
its Annual Report on Form 10-K.
The accompanying unaudited consolidated financial statements include all adjustments (consisting
only of normal recurring accruals) which, in the opinion of management, are necessary for a fair
presentation of financial position, results of operations and cash flows. Results of operations
for interim periods are not necessarily indicative of results to be expected for a full year.
Use of Estimates in Preparing Financial Statements The preparation of financial statements in
conformity with accounting principles generally accepted in the United States of America requires
management to make estimates and assumptions that affect the reported amounts of assets and
liabilities and disclosure of contingent assets and liabilities at the date of the financial
statements and the reported amounts of revenues and expenses during the reporting period. Actual
results could differ from those estimates.
Revenue Recognition Revenues are recognized on large, long-term construction contracts meeting
the criteria of Statement of Position 81-1, Accounting for Performance of Construction-Type and
Certain Production-Type Contracts (SOP 81-1), using the percentage-of-completion method based
upon the ratio of costs incurred to total estimated costs at completion. Contract price and cost
estimates are reviewed periodically as work progresses and adjustments proportionate to the
percentage of completion are reflected in contract revenues in the reporting period when such
estimates are revised. Changes in job performance, job conditions and estimated profitability,
including those arising from contract penalty provisions, change orders and final contract
settlements may result in revisions to costs and income and are recognized in the period in which
the revisions are determined. As allowed by SOP 81-1, revenue is recognized on smaller, short-term
construction contracts using the completed contract method. Provisions for estimated losses on
uncompleted construction contracts are made in the period in which such losses are determined.
Revenues for direct sales of equipment and other ancillary products not provided in conjunction
with the performance of construction contracts are recognized at the date of delivery to, and
acceptance by, the customer. Provisions for estimated warranty obligations are made in the period
in which the sales occur.
Contracts for the Companys mineral exploration drilling services are billable based on the
quantity of drilling performed. Thus, revenues for these drilling contracts are recognized on the
basis of actual footage or meterage drilled.
Revenues for the sale of oil and gas by the Companys energy division are recognized on the basis
of volumes sold at the time of delivery to an end user or an interstate pipeline, net of amounts
attributable to royalty or working interest holders.
The Companys revenues are presented net of taxes imposed on revenue-producing transactions with
its customers, such as, but not limited to, sales, use, value-added, and some excise taxes.
Oil and gas properties and mineral interests The Company follows the full-cost method of
accounting for oil and gas properties. Under this method, all productive and nonproductive costs
incurred in connection with the exploration for and development of oil and gas reserves are
capitalized. Such capitalized costs include lease acquisition, geological and geophysical work,
delay rentals, drilling, completing and equipping oil and gas wells, and salaries, benefits and
other internal salary-related costs directly attributable to these activities. Costs associated
with production and general corporate activities are expensed in the period incurred. Normal
dispositions of oil and gas properties are accounted for as adjustments of capitalized costs, with
no gain or loss recognized.
The Company is required to review the carrying value of its oil and gas properties each quarter
under the full cost accounting rules of the SEC. Under these rules, capitalized costs of proved
oil and gas properties, as adjusted for asset retirement obligations, may not exceed the present
value of estimated future net revenues from proved reserves, discounted at 10% (the ceiling
test). Application of the ceiling test generally requires pricing future revenue at the
unescalated prices in effect as
6
of the last day of the quarter, with effect given to the Companys fixed-price natural gas
contracts, and requires a write-down for accounting purposes if the ceiling is exceeded. Unproved
oil and gas properties are not amortized, but are assessed for impairment either individually or on
an aggregated basis using a comparison of the carrying values of the unproved properties to net
future cash flows. The Company believes at this time that the carrying value of its oil and gas
properties is appropriate.
Reserve Estimates The Companys estimates of natural gas reserves, by necessity, are projections
based on geologic and engineering data, and there are uncertainties inherent in the interpretation
of such data as well as the projection of future rates of production and the timing of development
expenditures. Reserve engineering is a subjective process of estimating underground accumulations
of gas that are difficult to measure. The accuracy of any reserve estimate is a function of the
quality of available data, engineering and geological interpretation and judgment. Estimates of
economically recoverable gas reserves and future net cash flows depend upon a number of variable
factors and assumptions, such as historical production from the area compared with production from
other producing areas, the assumed effects of regulations by governmental agencies and assumptions
governing natural gas prices, future operating costs, severance, ad valorem and excise taxes,
development costs and workover and remedial costs, all of which may in fact vary considerably from
actual results. For these reasons, estimates of the economically recoverable quantities of gas
attributable to any particular group of properties, classifications of such reserves based on risk
of recovery, and estimates of the future net cash flows expected there from may vary substantially.
Any significant variance in the assumptions could materially affect the estimated quantity and
value of the reserves, which could affect the carrying value of the Companys oil and gas
properties and the rate of depletion of the oil and gas properties. Actual production, revenues
and expenditures with respect to the Companys reserves will likely vary from estimates, and such
variances may be material.
Goodwill and Other Intangibles Goodwill and other intangible assets with indefinite useful lives
are not amortized, and instead are periodically tested for impairment. The Company performs its
annual impairment test as of December 31 each year, or more frequently if events or changes in
circumstances indicate that an asset might be impaired. The process of evaluating goodwill for
impairment involves the determination of the fair value of the Companys reporting units. Inherent
in such fair value determinations are certain judgments and estimates, including the interpretation
of current economic indicators and market valuations, and assumptions about the Companys strategic
plans with regard to its operations. The Company believes at this time that the carrying value of
the remaining goodwill is appropriate, although to the extent additional information arises or the
Companys strategies change, it is possible that the Companys conclusions regarding impairment of
the remaining goodwill could change and result in a material effect on its financial position or
results of operations.
Other Long-lived Assets In the event of an indication of possible impairment, the Company
evaluates the fair value and future benefits of long-lived assets, including the Companys gas
transportation facilities and equipment, by performing an analysis of the anticipated future net
cash flows of the related long-lived assets and reducing their carrying value by the excess, if
any, of the result of such calculation. The Company believes at this time that the carrying values
and useful lives of its long-lived assets continue to be appropriate.
Cash and Cash Equivalents The Company considers investments with an original maturity of three
months or less when purchased to be cash equivalents. As of April 30, 2008 and January 31, 2008,
the Companys cash equivalents included $41,000,000 and $56,000,000 of short term commercial paper.
The Companys cash equivalents are subject to potential credit risk. The Companys cash management
and investment policies restrict investments to investment grade, highly liquid securities. The
carrying value of cash and cash equivalents approximates fair value.
Restricted Cash Included in restricted cash are escrow funds associated with various acquisitions
as described in Note 2.
Accrued Insurance Expense The Company maintains insurance programs where it is responsible for a
certain amount of each claim up to a self-insured limit. Estimates are recorded for health and
welfare, property and casualty insurance costs that are associated with these programs. These
costs are estimated based on actuarially determined projections of future payments under these
programs. Should a greater amount of claims occur compared to what was estimated or costs of the
medical profession increase beyond what was anticipated, reserves recorded may not be sufficient
and additional costs to the consolidated financial statements could be required.
Costs estimated to be incurred in the future for employee medical benefits, property, workers
compensation and casualty insurance programs resulting from claims which have occurred are accrued
currently. Under the terms of the Companys agreement with the various insurance carriers
administering these claims, the Company is not required to remit the total premium until the claims
are actually paid by the insurance companies. These costs are not expected to significantly impact
liquidity in future periods.
Income Taxes Income taxes are provided using the asset/liability method, in which deferred taxes
are recognized for the tax
7
consequences of temporary differences between the financial statement
carrying amounts and tax bases of existing assets and liabilities. Deferred tax assets are
reviewed for recoverability and valuation allowances are provided as necessary. Provision for U.S.
income taxes on undistributed earnings of foreign subsidiaries and affiliates is made only on those
amounts in excess of funds considered to be invested indefinitely. In general, the Company records
income tax expense during interim periods based on its best estimate of the full years effective
tax rate. However, income tax expense relating to adjustments to the Companys liabilities for FIN
48, Accounting for Uncertainty in Income Taxes, an interpretation of FASB Statement 109
(FIN48), is accounted for discretely in the interim period in which it occurs.
As of April 30 and January 31, 2008, the total amount of unrecognized tax benefits recorded under
FIN 48 was $7,182,000 and $6,642,000, respectively, of which substantially all would affect the
effective tax rate if recognized. The Company does not expect the unrecognized tax benefits to
change materially within the next 12 months. The Company classifies uncertain tax positions as
non-current income tax liabilities unless expected to be paid in one year. The Company reports
income tax-related interest and penalties as a component of income tax expense. As of April 30
and January 31, 2008, the total amount of accrued income tax-related interest and penalties
included in the balance sheet was $2,950,000 and $2,752,000, respectively.
Litigation and Other Contingencies The Company is involved in litigation incidental to its
business, the disposition of which is not expected to have a material effect on the Companys
business, financial position, results of operations or cash flows. It is possible, however, that
future results of operations for any particular quarterly or annual period could be materially
affected by changes in the Companys assumptions related to these proceedings. The Company accrues
its best estimate of the probable cost for the resolution of legal claims. Such estimates are
developed in consultation with outside counsel handling these matters and are based upon a
combination of litigation and settlement strategies. To the extent additional information arises or
the Companys strategies change, it is possible that the Companys estimate of its probable
liability in these matters may change.
Derivatives The Company follows SFAS No. 133, Accounting for Derivative Instruments and Hedging
Activities (SFAS 133), as amended, which requires derivative financial instruments to be
recorded on the balance sheet at fair value and establishes criteria for designation and
effectiveness of hedging relationships. Under SFAS 133, the Company accounts for its unrealized
hedges of forecasted costs as cash flow hedges, such that changes in fair value for the effective
portion of hedge contracts, if material, are recorded in accumulated other comprehensive income in
stockholders equity. Changes in the fair value of the effective portion of hedge contracts are
recognized in accumulated other comprehensive income until the hedged item is recognized in
operations. The ineffective portion of the derivatives change in fair value, if any, is
immediately recognized in operations. In addition, the Company has entered into fixed-price
natural gas contracts to manage fluctuations in the price of natural gas. These contracts result
in the Company physically delivering gas, and as a result, are exempt from the requirements of SFAS
133 under the normal purchases and sales exception. Accordingly, the contracts are not reflected in
the balance sheet at fair value and revenues from the contracts are recognized as the natural gas
is delivered under the terms of the contracts (see Note 5 for disclosure regarding the fair value
of derivative instruments). The Company does not enter into derivative financial instruments for
speculative or trading purposes.
Earnings per share Earnings per share are based upon the weighted average number of common and
dilutive equivalent shares outstanding. Options to purchase common stock and unvested restricted stock are included based on the
treasury stock method for dilutive earnings per share, except when their effect is antidilutive.
Share-based compensation The Company adopted SFAS No. 123R (revised December 2004), Share-Based
Compensation effective February 1, 2006, which requires the recognition of all share-based
instruments in the financial statements and establishes a fair-value measurement of the associated
costs. The Company elected to adopt the standard using the Modified Prospective Method which
requires recognition of all unvested share-based instruments as of the effective date over the
remaining term of the instrument. As of April 30, 2008, the Company had unrecognized compensation
expense of $8,415,000 to be recognized over a weighted average period of 2.64 years. The Company
determines the fair value of stock-based compensation granted in the form of stock options using
the Black-Scholes model.
Consolidated Statements of Cash Flows Highly liquid investments with an original maturity of
three months or less at the time of purchase are considered cash equivalents.
Supplemental Cash Flow Information The amounts paid for income taxes, net of refunds, and
interest are as follows (in thousands):
8
|
|
|
|
|
|
|
|
|
|
|
Three Months |
|
|
Ended April 30, |
|
|
2008 |
|
2007 |
Income taxes |
|
$ |
1,171 |
|
|
$ |
1,573 |
|
Interest |
|
|
943 |
|
|
|
2,363 |
|
New Accounting Pronouncements In September 2006, the FASB issued SFAS 157, Fair Value
Measurements ( SFAS 157), which defines fair value, establishes a framework for measuring fair
value in generally accepted accounting principles, and expands disclosures about fair value
measurements. SFAS 157 does not require any new value measurements, but provides guidance on how to
measure fair value by providing a fair value hierarchy used to classify the source of the
information. On February 1, 2008 the Company adopted SFAS157 for its financial assets and
liabilities. The adoption of SFAS 157 did not impact the Companys financial position, results of
operations, liquidity or disclosures as there are no financial assets or liabilities that are
measured at fair value on a recurring basis. In February 2008, the FASB issued Staff Position
157-2, Effective Date of FASB Statement No. 157 (FSP 157-2), which delays the effective date of
SFAS 157 for all nonfinancial assets and nonfinancial liabilities, except those that are recognized
or disclosed at fair value in the financial statements on a recurring basis (at least annually),
until fiscal years beginning after November 15, 2008, and interim periods within those fiscal
years. These nonfinancial items include assets and liabilities such as reporting units measured at
fair value in a goodwill impairment test and nonfinancial assets acquired and liabilities assumed
in a business combination. The adoption of SFAS 157 for those nonfinancial assets within the scope
of FSP 157-2 is not expected to have a material impact on the Companys financial position,
results of operations or liquidity.
In September 2006, the FASB issued SFAS 158, Employers Accounting for Defined Benefit Pension and
Other Postretirement Plans (SFAS 158), which requires a company that sponsors a postretirement
benefit plan to fully recognize, as an asset or liability, the overfunded or underfunded status of
its benefit plan(s) in its year-end balance sheet. These provisions of SFAS 158 were effective for
the Companys fiscal year ended January 31, 2007. In addition, SFAS 158 also generally requires a
company to measure its plan assets and benefit obligations as of its fiscal year-end balance sheet
date. The Company elected to apply the transition option under which a 13-month measurement was
determined as of December 31, 2007 that covers the period until the fiscal year-end measurement is
required on January 31, 2009. As a result, the Company recorded an approximate $44,000 decrease to
retained earnings for the period ending April 30, 2008.
In February 2007, the FASB issued SFAS 159, The Fair Value Option for Financial Assets and
Financial Liabilities including an amendment of FASB Statement No. 115 (SFAS 159). SFAS 159
permits the measurement of specified financial instruments and warranty and insurance contracts at
fair value on a contract-by-contract basis, with changes in fair value recognized in earnings each
reporting period. The Company adopted this standard as of the period ending April 30, 2008. The
adoption of SFAS 159 did not impact our consolidated financial statements.
2. Acquisitions
On December 31, 2007 (the Tierdael Closing Date), the Company acquired certain assets and
liabilities of Tierdael Construction (Tierdael), a pipeline and utility construction contractor
in Denver which was combined with a similar service line acquired in the acquisition of Reynolds,
Inc. The purchase price for Tierdael was $7,110,000, consisting of cash of $6,646,000, assumed
liabilities of $226,000 and costs of $238,000. The cash portion of the purchase price is subject to
certain adjustments based on the value of working capital at the closing date, settlement of which
is expected in the second quarter of fiscal 2009. Any adjustment will be treated as an adjustment
of the total purchase price.
The preliminary purchase price has been allocated based on the fair value of the assets and
liabilities acquired, determined based on the Companys internal operational assessments and other
analyses. Such amounts may be subject to revision as Tierdael is integrated into the Company and
the revisions may be significant and will be recorded by the Company as further adjustments to the
purchase price allocation.
Based on the Companys preliminary allocation of the purchase price, the acquisition had the
following effect on the Companys consolidated financial position as of the Tierdael Closing Date:
|
|
|
|
|
(in thousands) |
|
|
|
|
|
Working capital |
|
$ |
3,983 |
|
Property and equipment |
|
|
3,127 |
|
|
Total purchase price |
|
$ |
7,110 |
|
|
9
The results of operations of Tierdael have been included in the Companys consolidated statements
of income commencing with the Tierdael Closing Date. Assuming Tierdael had been acquired as of the
beginning of each period, the unaudited pro forma consolidated revenues, net income and net income
per share would be as follows:
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
April 30, |
(in thousands, except per share data) |
|
2008 |
|
2007 |
|
Revenues |
|
$ |
244,544 |
|
|
$ |
207,746 |
|
Net income |
|
|
10,562 |
|
|
|
8,381 |
|
Basic earnings per share |
|
$ |
0.55 |
|
|
$ |
0.54 |
|
|
Diluted earnings per share |
|
$ |
0.55 |
|
|
$ |
0.53 |
|
|
The pro forma information provided above is not necessarily indicative of the results of operations
that would actually have resulted if the acquisition was made as of those dates or of results that
may occur in the future. Pro forma results include adjustments for interest expense on the cash
purchase price.
On November 30, 2007 (the SolmeteX Closing Date), the Company acquired certain assets and
liabilities of SolmeteX, Inc. (SolmeteX), a water and wastewater research and development
business and a supplier of wastewater filtration products to the dental market. The purchase price
for SolmeteX was $13,586,000, consisting of cash of $13,500,000 and costs of $86,000. In addition,
there is contingent consideration up to a maximum of $1,000,000 (the SolmeteX Earnout Amount),
which is based on a percentage of the amount of SolmeteXs revenues during the 36 months following
the acquisition. Any portion of the SolmeteX Earnout Amount that is ultimately paid will be
accounted for as additional purchase consideration.
The preliminary purchase price has been allocated based on the fair value of the assets and
liabilities acquired, determined based on the Companys internal operational assessments,
appraisals and other analyses. Such amounts may be subject to revision as SolmeteX is integrated
into the Company and the revisions may be significant and will be recorded by the Company as
further adjustments to purchase price allocation.
Based on the Companys preliminary allocation of the purchase price, the acquisition had the
following effect on the Companys consolidated financial position as of the SolmeteX Closing Date:
|
|
|
|
|
(in thousands) |
|
|
|
|
|
Working capital |
|
$ |
64 |
|
Property and equipment |
|
|
115 |
|
Goodwill |
|
|
7,270 |
|
Tradenames |
|
|
2,962 |
|
Patents |
|
|
2,543 |
|
Other intangible assets |
|
|
551 |
|
Deferred income taxes |
|
|
81 |
|
|
Total purchase price |
|
$ |
13,586 |
|
|
Of the $6,056,000 of acquired identifiable intangible assets, $21,000 was assigned to research and
development assets that were written off in selling, general and administrative expenses at the
date of acquisition in accordance with FASB Interpretation 4, Applicability of FASB Statement No.
2 to Business Combinations Accounted for by the Purchase Method. The remaining $6,035,000 of
acquired identifiable intangible assets have a weighted-average useful life of approximately 15.4
years, comprised of trade names (15-year weighted-average useful life), patents (15-year
weighted-average useful life), and other assets (20-year average useful life). The $7,270,000 of
goodwill was assigned to the water infrastructure segment. Of that total amount, $7,053,000 is
expected to be deductible for tax purposes.
The results of operations of SolmeteX have been included in the Companys consolidated statements
of income commencing with the SolmeteX Closing Date. Assuming SolmeteX had been acquired as of the
beginning of each period, the unaudited pro forma consolidated revenues, net income and net income per
share would be as follows:
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
April 30, |
(in thousands, except per share data) |
|
2008 |
|
2007 |
|
Revenues |
|
$ |
244,544 |
|
|
$ |
202,617 |
|
Net income |
|
|
10,562 |
|
|
|
7,961 |
|
Basic earnings per share |
|
$ |
0.55 |
|
|
$ |
0.51 |
|
|
Diluted earnings per share |
|
$ |
0.55 |
|
|
$ |
0.51 |
|
|
10
The pro forma information provided above is not necessarily indicative of the results of operations
that would actually have resulted if the acquisition was made as of those dates or of results that
may occur in the future. Pro forma results include adjustments for interest expense on the cash
purchase price.
On June 16, 2006, the Company acquired 100% of the stock of Collector Wells International, Inc.
(CWI), a privately held specialty water services company that designs and constructs water supply
systems. CWI will be combined with a similar service line acquired in the acquisition of Reynolds,
Inc. In addition to the initial purchase price, there is contingent consideration up to a maximum
of $1,400,000 (the CWI Earnout Amount), which is based on a percentage of the amount by which
CWIs earnings before interests, taxes, depreciation and amortization exceed a threshold amount
during the thirty-six months following the acquisition. If earned, up to 20% of the CWI Earnout
Amount may be paid with Layne common stock, at the Companys discretion. Any portion of the CWI
Earnout Amount which is ultimately paid will be accounted for as additional purchase consideration.
3. Goodwill and Other Intangible Assets
Goodwill and other intangible assets consist of the following (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
April 30, 2008 |
|
|
January 31, 2008 |
|
|
|
|
|
|
|
|
|
|
|
Weighted |
|
|
|
|
|
|
|
|
|
|
Weighted |
|
|
|
|
|
|
|
|
|
|
|
Average |
|
|
|
|
|
|
|
|
|
|
Average |
|
|
|
Gross |
|
|
|
|
|
|
Amortization |
|
|
Gross |
|
|
|
|
|
|
Amortization |
|
|
|
Carrying |
|
|
Accumulated |
|
|
Period in |
|
|
Carrying |
|
|
Accumulated |
|
|
Period in |
|
|
|
Amount |
|
|
Amortization |
|
|
years |
|
|
Amount |
|
|
Amortization |
|
|
years |
|
Goodwill |
|
$ |
85,706 |
|
|
$ |
|
|
|
|
|
|
|
$ |
85,706 |
|
|
$ |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortizable intangible assets: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Tradenames |
|
$ |
18,962 |
|
|
$ |
(1,667 |
) |
|
|
29 |
|
|
$ |
18,962 |
|
|
$ |
(1,464 |
) |
|
|
29 |
|
Customer-related |
|
|
332 |
|
|
|
(332 |
) |
|
|
2 |
|
|
|
332 |
|
|
|
(340 |
) |
|
|
2 |
|
Patents |
|
|
2,902 |
|
|
|
(380 |
) |
|
|
14 |
|
|
|
2,902 |
|
|
|
(307 |
) |
|
|
14 |
|
Non-competition agreements |
|
|
379 |
|
|
|
(284 |
) |
|
|
5 |
|
|
|
379 |
|
|
|
(273 |
) |
|
|
5 |
|
Other |
|
|
1,292 |
|
|
|
(577 |
) |
|
|
22 |
|
|
|
1,292 |
|
|
|
(553 |
) |
|
|
22 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total amortizable intangible assets |
|
$ |
23,867 |
|
|
$ |
(3,240 |
) |
|
|
|
|
|
$ |
23,867 |
|
|
$ |
(2,937 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortizable intangible assets are being amortized over their estimated useful lives of two to 40
years with a weighted average amortization period of 26 years. Total amortization expense for
other intangible assets was $303,000 and $292,000 for the quarters ended April 30, 2008 and 2007,
respectively.
The carrying amount of goodwill attributed to each operating segment was as follows (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Water |
|
|
|
|
|
|
Energy |
|
|
Infrastructure |
|
|
Total |
|
Balance February 1, 2008 |
|
$ |
950 |
|
|
$ |
84,756 |
|
|
$ |
85,706 |
|
Additions |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance, April 30, 2008 |
|
$ |
950 |
|
|
$ |
84,756 |
|
|
$ |
85,706 |
|
|
|
|
|
|
|
|
|
|
|
4. Indebtedness
On July 31, 2003, the Company entered into an agreement (Master Shelf Agreement) whereby it could
issue up to $60,000,000 in unsecured notes. Upon closing, the Company issued $40,000,000 of notes
(Series A Senior Notes) under the Master Shelf Agreement. The Series A Senior Notes bear a fixed
interest rate of 6.05% and are due on August 2, 2010, with annual principal payments of $13,333,000
beginning July 31, 2008. Proceeds from the issuance were used to refinance borrowings outstanding
under the Companys previous term loan and revolving credit facility. The Company issued an
additional $20,000,000 of notes under the Master Shelf Agreement in October 2004 (Series B Senior
Notes). The Series B Senior Notes bear a fixed interest rate of 5.40% and are due on September
29, 2011, with annual principal payments of $6,667,000 beginning September 29, 2009. Proceeds of
the issuance were used to finance an acquisition and for general corporate purposes. As of October
15, 2007 the Company amended the Master Shelf Agreement to increase the amount of senior notes
available to be issued to $105,000,000, which created an available facility amount of $45,000,000,
and reinstated and extended the available issuance period to September 15, 2009.
11
The Company also maintains a revolving credit facility under an Amended and Restated Loan Agreement
(the Credit Agreement) with LaSalle Bank National Association, as Administrative Agent and as
Lender (the Administrative Agent), and the other Lenders listed therein (the Lenders), which
contains a revolving loan commitment of $200,000,000, less any outstanding letter of credit
commitments (which are subject to a $30,000,000 sublimit).
The Credit Agreement provides for interest at variable rates equal to, at the Companys option, a
LIBOR rate plus 0.75% to 2.00%, or a base rate, as defined in the Credit Agreement plus up to
0.50%, depending upon the Companys leverage ratio. The Credit Agreement is unsecured and is due
and payable November 15, 2011. On April 30, 2008, there were letters of credit of $11,716,000 and
no borrowings outstanding on the Credit Agreement resulting in available capacity of
$188,284,000.
The Master Shelf Agreement and the Credit Agreement contain certain covenants including
restrictions on the incurrence of additional indebtedness and liens, investments, acquisitions,
transfer or sale of assets, transactions with affiliates, payment of dividends and certain
financial maintenance covenants, including among others, fixed charge coverage, maximum debt to
EBITDA and minimum tangible net worth. The Company was in compliance with its covenants as of
April 30, 2008.
Debt outstanding as of April 30, 2008 and January 31, 2008 was as follows (in thousands):
|
|
|
|
|
|
|
|
|
|
|
April 30, |
|
|
January 31, |
|
|
|
2008 |
|
|
2008 |
|
Long-term debt: |
|
|
|
|
|
|
|
|
Credit Agreement |
|
$ |
|
|
|
$ |
|
|
Senior Notes |
|
|
60,000 |
|
|
|
60,000 |
|
|
|
|
|
|
|
|
Total debt |
|
|
60,000 |
|
|
|
60,000 |
|
|
|
|
|
|
|
|
Less current maturities |
|
|
(13,333 |
) |
|
|
(13,333 |
) |
|
|
|
|
|
|
|
Total long-term debt |
|
$ |
46,667 |
|
|
$ |
46,667 |
|
|
|
|
|
|
|
|
5. Derivatives
The Companys energy division is exposed to fluctuations in the price of natural gas and has
entered into fixed-price physical delivery contracts to manage natural gas price risk for a portion
of its production. As of April 30, 2008, the Company had committed to deliver 8,400,000 million
British Thermal Units (MMBtu) of natural gas through March 2010 at prices ranging from $7.82 to
$8.73 per MMBtu through March 2009 and from $7.82 to $9.13 per MMBtu from April 2009 to March 2010.
The fixed-price physical delivery contracts will result in the physical delivery of natural gas,
and as a result, are exempt from the requirements of SFAS 133 under the normal purchases and sales
exception. Accordingly, the contracts are not reflected in the balance sheet at fair value and
revenues from the contracts are recognized as the natural gas is delivered under the terms of the
contracts. The estimated fair value of such contracts at April 30, 2008 was a loss of $4,929,000.
Additionally, the Company has foreign operations that have significant costs denominated in foreign
currencies, and thus is exposed to risks associated with changes in foreign currency exchange
rates. At any point in time, the Company might use various hedge instruments, primarily foreign
currency option contracts, to manage the exposures associated with forecasted expatriate labor
costs and purchases of operating supplies. The Company does not enter into foreign currency
derivative financial instruments for speculative or trading purposes.
6. Other Comprehensive Income (Loss)
Components of other comprehensive income are summarized as follows (in thousands):
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
|
April 30, |
|
|
|
2008 |
|
|
2007 |
|
Net income |
|
$ |
10,562 |
|
|
$ |
8,153 |
|
Other comprehensive income (loss), net of taxes: |
|
|
|
|
|
|
|
|
Foreign currency translation adjustments |
|
|
461 |
|
|
|
253 |
|
|
|
|
|
|
|
|
Comprehensive income |
|
$ |
11,023 |
|
|
$ |
8,406 |
|
|
|
|
|
|
|
|
The components of accumulated other comprehensive loss for the three months ended April 30, 2008
and 2007 are as
12
follows (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated |
|
|
|
Cumulative |
|
|
Unrecognized |
|
|
Other |
|
|
|
Translation |
|
|
Pension |
|
|
Comprehensive |
|
|
|
Adjustment |
|
|
Liability |
|
|
Loss |
|
Balance, February 1, 2008 |
|
$ |
(6,391 |
) |
|
$ |
(596 |
) |
|
$ |
(6,987 |
) |
Period change |
|
|
461 |
|
|
|
|
|
|
|
461 |
|
|
|
|
|
|
|
|
|
|
|
Balance, April 30, 2008 |
|
$ |
(5,930 |
) |
|
$ |
(596 |
) |
|
$ |
(6,526 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated |
|
|
|
Cumulative |
|
|
Unrecognized |
|
|
Other |
|
|
|
Translation |
|
|
Pension |
|
|
Comprehensive |
|
|
|
Adjustment |
|
|
Liability |
|
|
Loss |
|
Balance, February 1, 2007 |
|
$ |
(7,151 |
) |
|
$ |
(1,302 |
) |
|
$ |
(8,453 |
) |
Period change |
|
|
253 |
|
|
|
|
|
|
|
253 |
|
|
|
|
|
|
|
|
|
|
|
Balance, April 30, 2007 |
|
$ |
(6,898 |
) |
|
$ |
(1,302 |
) |
|
$ |
(8,200 |
) |
|
|
|
|
|
|
|
|
|
|
7. Employee Benefit Plans
The Company sponsors a pension plan covering certain hourly employees not covered by
union-sponsored, multi-employer plans. Benefits are computed based mainly on years of service.
The Company makes annual contributions to the plan substantially equal to the amounts required to
maintain the qualified status of the plans. Contributions are intended to provide for benefits
related to past and current service with the Company. Effective December 31, 2003, the Company
froze the pension plan. Benefits will no longer be accrued after December 31, 2003, and no further
employees will be added to the Plan. The Company expects to maintain the assets of the Plan to pay
normal benefits accrued through December 31, 2003. Assets of the plan consist primarily of stocks,
bonds and government securities.
Net periodic pension cost for the three months ended April 30, 2008 and 2007 includes the following
components (in thousands):
|
|
|
|
|
|
|
|
|
|
|
Three Months |
|
|
|
Ended April 30, |
|
|
|
2008 |
|
|
2007 |
|
Service cost |
|
$ |
24 |
|
|
$ |
22 |
|
Interest cost |
|
|
113 |
|
|
|
113 |
|
Expected return on assets |
|
|
(134 |
) |
|
|
(132 |
) |
Net amortization |
|
|
54 |
|
|
|
68 |
|
|
|
|
|
|
|
|
Net periodic pension cost |
|
$ |
57 |
|
|
$ |
71 |
|
|
|
|
|
|
|
|
The Company also provides supplemental retirement benefits to its chief executive officer.
Benefits are computed based on the compensation earned during the highest five consecutive years of
employment reduced for a portion of Social Security benefits and an annuity equivalent of the chief
executives defined contribution plan balance. The Company does not contribute to the plan or
maintain any investment assets related to the expected benefit obligation. The Company has
recognized the full amount of its actuarially determined pension liability. Net periodic pension
cost of the supplemental retirement benefits for the three months ended April 30, 2008 and 2007
include the following components (in thousands):
|
|
|
|
|
|
|
|
|
|
|
Three Months |
|
|
|
Ended April 30, |
|
|
|
2008 |
|
|
2007 |
|
Service cost |
|
$ |
44 |
|
|
$ |
25 |
|
Interest cost |
|
|
26 |
|
|
|
22 |
|
|
|
|
|
|
|
|
Net periodic pension cost |
|
$ |
70 |
|
|
$ |
47 |
|
|
|
|
|
|
|
|
8. Stock and Stock Option Plans
In October 1998, the Company adopted a Rights Agreement whereby the Company has authorized and
declared a dividend of one preferred share purchase right (Right) for each outstanding common
share of the Company. Subject to limited exceptions,
13
the Rights are exercisable if a person or
group acquires or announces a tender offer for 25% or more of the Companys common stock. Each
Right will entitle shareholders to buy one one-hundredth of a share of a newly created Series A
Junior Participating Preferred Stock of the Company at an exercise price of $45.00. The Company is
entitled to redeem the Right at $0.01 per Right at any time before a person has acquired 25% or
more of the Companys outstanding common stock. The Rights expire 10 years from the date of grant.
The Company has stock option and employee incentive plans that provide for the granting of options
to purchase or the issuance of shares of common stock up to an aggregate of 1,450,000 shares of
common stock at a price fixed by the Board of Directors or a committee. As of April 30, 2008, there
were 478,000 shares available to be granted under the plans. The Company has the ability to issue
shares under the plans either from new issuances or from treasury, although it has previously
always issued new shares and expects to continue to issue new shares in the future.
For the three months ended April 30, 2008, the Company granted approximately 34,000 restricted
shares which generally ratably vest over periods of 1-4 years from the grant date.
The Company recognized $342,000 and $7,000 in compensation cost related to nonvested shares for the
periods ended April 30, 2008 and 2007, respectively. A summary of nonvested share activity for the
quarter ended April 30, 2008, is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Average |
|
Intrinsic |
|
|
Number of |
|
Grant Date |
|
Value (in |
|
|
Shares |
|
Fair Value |
|
thousands) |
|
Nonvested stock at
January 31, 2008 |
|
|
73,863 |
|
|
$ |
42.76 |
|
|
|
|
|
|
|
|
|
|
Granted |
|
|
33,825 |
|
|
|
35.71 |
|
|
|
|
|
Vested |
|
|
|
|
|
|
|
|
|
|
|
|
|
Nonvested stock at
April 30, 2008 |
|
|
107,688 |
|
|
$ |
40.55 |
|
|
$ |
3,406 |
|
|
Significant option groups outstanding at April 30, 2008, related exercise price and remaining
contractual term follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Remaining |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Contractual |
Grant |
|
Options |
|
Options |
|
Exercise |
|
Term |
Date |
|
Outstanding |
|
Exercisable |
|
Price |
|
(Months) |
|
4/99 |
|
|
9,773 |
|
|
|
9,773 |
|
|
|
4.125 |
|
|
|
12 |
|
4/99 |
|
|
24,875 |
|
|
|
24,875 |
|
|
|
5.250 |
|
|
|
12 |
|
2/00 |
|
|
3,500 |
|
|
|
3,500 |
|
|
|
5.500 |
|
|
|
22 |
|
4/00 |
|
|
14,794 |
|
|
|
14,794 |
|
|
|
3.495 |
|
|
|
24 |
|
6/04 |
|
|
25,000 |
|
|
|
25,000 |
|
|
|
16.600 |
|
|
|
74 |
|
6/04 |
|
|
168,916 |
|
|
|
100,166 |
|
|
|
16.650 |
|
|
|
74 |
|
6/05 |
|
|
12,000 |
|
|
|
12,000 |
|
|
|
17.540 |
|
|
|
86 |
|
9/05 |
|
|
187,500 |
|
|
|
62,500 |
|
|
|
23.050 |
|
|
|
89 |
|
1/06 |
|
|
200,231 |
|
|
|
95,116 |
|
|
|
27.870 |
|
|
|
93 |
|
6/06 |
|
|
12,000 |
|
|
|
12,000 |
|
|
|
29.290 |
|
|
|
98 |
|
6/06 |
|
|
70,000 |
|
|
|
17,500 |
|
|
|
29.290 |
|
|
|
98 |
|
6/07 |
|
|
70,000 |
|
|
|
|
|
|
|
42.260 |
|
|
|
110 |
|
7/07 |
|
|
33,000 |
|
|
|
|
|
|
|
42.760 |
|
|
|
111 |
|
9/07 |
|
|
3,000 |
|
|
|
|
|
|
|
55.480 |
|
|
|
113 |
|
2/08 |
|
|
74,524 |
|
|
|
|
|
|
|
35.710 |
|
|
|
117 |
|
|
|
|
|
909,113 |
|
|
|
377,224 |
|
|
|
|
|
|
|
|
|
|
All options were granted at an exercise price equal to the fair market value of the Companys
common stock at the date of grant. The options have terms of 5 to 10 years from the date of grant
and generally vest ratably over periods of 4 to 5 years. Transactions for stock options for the
period ended April 30, 2008 were as follows:
14
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock Options |
|
|
|
|
|
|
|
|
|
|
|
Weighted |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Average |
|
|
|
|
|
|
|
|
|
|
Weighted |
|
|
Remaining |
|
|
Intrinsic |
|
|
|
Number of |
|
|
Average |
|
|
Contractual Term |
|
|
Value |
|
|
|
Shares |
|
|
Exercise Price |
|
|
(years) |
|
|
(in thousands) |
|
Stock Option Activity Summary: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding at February 1, 2008 |
|
|
849,950 |
|
|
$ |
24.541 |
|
|
|
7.360 |
|
|
$ |
13,955 |
|
Granted |
|
|
74,524 |
|
|
|
35.710 |
|
|
|
|
|
|
|
|
|
Exercised |
|
|
(15,361 |
) |
|
|
22.074 |
|
|
|
|
|
|
$ |
224 |
|
Canceled |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Forfeited |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Expired |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding at April 30, 2008 |
|
|
909,113 |
|
|
$ |
25.498 |
|
|
|
7.330 |
|
|
$ |
14,472 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Shares Exercisable |
|
|
377,224 |
|
|
$ |
19.857 |
|
|
|
6.280 |
|
|
$ |
8,278 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The aggregate intrinsic value was calculated using the difference between the current market price
and the exercise price for only those options that have an exercise price less than the current
market price.
9. Operating Segments
The Company is a multinational company that provides sophisticated services and related products to
a variety of markets, as well as being a producer of unconventional natural gas for the energy
market. Management defines the Companys operational organizational structure into discrete
divisions based on its primary product lines. Each division comprises a combination of individual
district offices, which primarily offer similar types of services and serve similar types of
markets. The Companys reportable segments are defined as follows:
Water Infrastructure Division
This division provides a full line of water-related services and products including hydrological
studies, site selection, well design, drilling and development, pump installation, and well
rehabilitation. The divisions offerings also include the design and construction of water and
wastewater treatment facilities, the provision of filter media and membranes to treat volatile
organics and other contaminants such as nitrates, iron, manganese, arsenic, radium and radon in
groundwater, Ranney collector wells, sewer rehabilitation and water and wastewater transmission
lines. The division also offers environmental services to assess and monitor groundwater
contaminants.
Mineral Exploration Division
This division provides a complete range of drilling services for the mineral exploration industry.
Its aboveground and underground drilling activities include all phases of core drilling, diamond,
reverse circulation, dual tube, hammer and rotary air-blast methods.
Energy Division
This division focuses on exploration and production of unconventional gas properties, primarily
concentrating on projects in the mid-continent region of the United States.
Other
Other includes two small specialty energy service companies and any other specialty operations not
included in one of the other divisions.
Financial information (in thousands) for the Companys operating segments are presented below.
Intersegment revenues are accounted for based on the fair market value of the services provided.
Unallocated corporate expenses primarily consist of general and administrative functions performed
on a company-wide basis and benefiting all operating segments. These costs include accounting,
financial reporting, internal audit, safety, treasury, corporate and securities law, tax
compliance, certain executive management (chief executive officer, chief financial officer and
general counsel) and board of directors.
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
|
April 30, |
|
|
|
2008 |
|
|
2007 |
|
Revenues |
|
|
|
|
|
|
|
|
Water infrastructure |
|
$ |
180,572 |
|
|
$ |
153,509 |
|
15
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
|
April 30, |
|
|
|
2008 |
|
|
2007 |
|
Mineral exploration |
|
|
51,094 |
|
|
|
37,097 |
|
Energy |
|
|
11,879 |
|
|
|
9,552 |
|
Other |
|
|
999 |
|
|
|
1,457 |
|
|
|
|
|
|
|
|
Total revenues |
|
$ |
244,544 |
|
|
$ |
201,615 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Equity in earnings of affiliates |
|
|
|
|
|
|
|
|
Mineral exploration |
|
$ |
2,497 |
|
|
$ |
1,491 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes |
|
|
|
|
|
|
|
|
Water infrastructure |
|
$ |
9,189 |
|
|
$ |
11,834 |
|
Mineral exploration |
|
|
11,636 |
|
|
|
5,751 |
|
Energy |
|
|
4,476 |
|
|
|
3,819 |
|
Other |
|
|
20 |
|
|
|
224 |
|
Unallocated corporate expenses |
|
|
(5,851 |
) |
|
|
(5,379 |
) |
Interest |
|
|
(941 |
) |
|
|
(2,430 |
) |
|
|
|
|
|
|
|
Total income before income taxes |
|
$ |
18,529 |
|
|
$ |
13,819 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Geographic Information: |
|
|
|
|
|
|
|
|
Revenues |
|
|
|
|
|
|
|
|
United States |
|
$ |
200,440 |
|
|
$ |
170,649 |
|
Africa/Australia |
|
|
26,674 |
|
|
|
17,911 |
|
Mexico |
|
|
10,800 |
|
|
|
8,212 |
|
Other foreign |
|
|
6,630 |
|
|
|
4,843 |
|
|
|
|
|
|
|
|
Total revenues |
|
$ |
244,544 |
|
|
$ |
201,615 |
|
|
|
|
|
|
|
|
10. Contingencies
The Companys drilling activities involve certain operating hazards that can result in personal
injury or loss of life, damage and destruction of property and equipment, damage to the surrounding
areas, release of hazardous substances or wastes and other damage to the environment, interruption
or suspension of drill site operations and loss of revenues and future business. The magnitude of
these operating risks is amplified when the Company, as is frequently the case, conducts a project
on a fixed-price, turnkey basis where the Company delegates certain functions to subcontractors
but remains responsible to the customer for the subcontracted work. In addition, the Company is
exposed to potential liability under foreign, federal, state and local laws and regulations,
contractual indemnification agreements or otherwise in connection with its services and products.
Litigation arising from any such occurrences may result in the Company being named as a defendant
in lawsuits asserting large claims. Although the Company maintains insurance protection that it
considers economically prudent, there can be no assurance that any such insurance will be
sufficient or effective under all circumstances or against all claims or hazards to which the
Company may be subject or that the Company will be able to continue to obtain such insurance
protection. A successful claim or damage resulting from a hazard for which the Company is not
fully insured could have a material adverse effect on the Company. In addition, the Company does
not maintain political risk insurance with respect to its foreign operations.
The Company is involved in various matters of litigation, claims and disputes which have arisen in
the ordinary course of the Companys business. The Company believes that the ultimate disposition
of these matters will not, individually and in the aggregate, have a material adverse effect upon
its business or consolidated financial position, results of operations or cash flows.
On April 30, 2008, Levelland/Hockley County Ethanol, LLC (Levelland) filed a Complaint against
the Company in the District Court for Hockley County, Texas. On May 28, 2008, the Company removed
the case to the United States District Court for the Northern District of Texas, Lubbock Division.
On June 2, 2008, Levelland filed a First Amended Complaint against the Company in the Federal
District Court for the Northern District of Texas, Lubbock Division. Levelland owns an ethanol
plant located in Levelland, Texas. In July 2007, Levelland entered into a lease agreement with the
Company for certain water treatment equipment for the ethanol plant. Levelland alleges that the
equipment leased from the Company fails to treat the water coming into the ethanol plant to
required levels. The First Amended Complaint seeks damages for breach of contract, breach of
warranty, violation of the Texas Deceptive Trade Practices Act, negligence, negligent
misrepresentation and fraud, in connection with the design and construction of the water treatment
facility. The Company believes that it has meritorious defenses to the claims, intends to
vigorously defend against them and does not believe that the
resolution of the claims will have a significant effect
on its financial statements.
Item 1A. Risk Factors
There have been no significant changes to the risk factors disclosed under Item 1A in our Annual
Report on Form 10-K for the year ended January 31, 2008.
16
Item 2. Managements Discussion and Analysis of Results of Operations and Financial Condition
Cautionary Language Regarding Forward-Looking Statements
This Form 10-Q may contain forward-looking statements within the meaning of Section 27A of the
Securities Act of 1933 and Section 21E of the Exchange Act of 1934. Such statements may include,
but are not limited to, statements of plans and objectives, statements of future economic
performance and statements of assumptions underlying such statements, and statements of
managements intentions, hopes, beliefs, expectations or predictions of the future. Forward looking
statements can often be identified by the use of forward-looking terminology, such as should,
intended, continue, believe, may, hope, anticipate, goal, forecast, plan,
estimate and similar words or phrases. Such statements are based on current expectations and are
subject to certain risks, uncertainties and assumptions, including but not limited to prevailing
prices for various commodities, unanticipated slowdowns in the Companys major markets, the risks
and uncertainties normally incident to the construction industry and exploration for and
development and production of oil and gas, the impact of competition, the effectiveness of
operational changes expected to increase efficiency and productivity, worldwide economic and
political conditions and foreign currency fluctuations that may affect worldwide results of
operations. Should one or more of these risks or uncertainties materialize, or should underlying
assumptions prove incorrect, actual results may vary materially and adversely from those
anticipated, estimated or projected. These forward-looking statements are made as of the date of
this filing, and the Company assumes no obligation to update such forward-looking statements or to
update the reasons why actual results could differ materially from those anticipated in such
forward-looking statements.
Results of Operations
The following table presents, for the periods indicated, the percentage relationship which certain
items reflected in the Companys consolidated statements of income bear to revenues and the
percentage increase or decrease in the dollar amount of such items period to period.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
Period-to-Period |
|
|
April 30, |
|
Change |
|
|
2008 |
|
2007 |
|
Three Months |
Revenues: |
|
|
|
|
|
|
|
|
|
|
|
|
Water infrastructure |
|
|
73.8 |
% |
|
|
76.2 |
% |
|
|
17.6 |
% |
Mineral exploration |
|
|
20.9 |
|
|
|
18.4 |
|
|
|
37.7 |
|
Energy |
|
|
4.9 |
|
|
|
4.7 |
|
|
|
24.4 |
|
Other |
|
|
0.4 |
|
|
|
0.7 |
|
|
|
(31.4 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total net revenues |
|
|
100.0 |
% |
|
|
100.0 |
% |
|
|
21.3 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of revenues |
|
|
74.4 |
% |
|
|
73.1 |
% |
|
|
23.6 |
|
Selling, general and administrative expenses |
|
|
13.5 |
|
|
|
14.6 |
|
|
|
12.4 |
|
Depreciation, depletion and amortization |
|
|
5.1 |
|
|
|
5.1 |
|
|
|
20.3 |
|
Other income (expense): |
|
|
|
|
|
|
|
|
|
|
|
|
Equity in earnings of affiliates |
|
|
1.0 |
|
|
|
0.7 |
|
|
|
67.5 |
|
Interest |
|
|
(0.4 |
) |
|
|
(1.2 |
) |
|
|
(61.3 |
) |
Other, net |
|
|
|
|
|
|
0.1 |
|
|
|
(122.2 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes |
|
|
7.6 |
|
|
|
6.9 |
|
|
|
34.1 |
|
Income tax expense |
|
|
3.3 |
|
|
|
2.9 |
|
|
|
40.6 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income |
|
|
4.3 |
% |
|
|
4.0 |
% |
|
|
29.5 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
17
Revenues, equity in earnings of affiliates and income before income taxes pertaining to the
Companys operating segments are presented below. Intersegment revenues are accounted for based on
the fair market value of the services provided. Unallocated corporate expenses primarily consist
of general and administrative functions performed on a company-wide basis and benefiting all
operating segments. These costs include accounting, financial reporting, internal audit, safety,
treasury, corporate and securities law, tax compliance, certain executive management (chief
executive officer, chief financial officer and general counsel), and board of directors. Operating
segment data is summarized as follows (in thousands):
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
|
April 30, |
|
|
|
2008 |
|
|
2007 |
|
Revenues |
|
|
|
|
|
|
|
|
Water infrastructure |
|
$ |
180,572 |
|
|
$ |
153,509 |
|
Mineral exploration |
|
|
51,094 |
|
|
|
37,097 |
|
Energy |
|
|
11,879 |
|
|
|
9,552 |
|
Other |
|
|
999 |
|
|
|
1,457 |
|
|
|
|
|
|
|
|
Total revenues |
|
$ |
244,544 |
|
|
$ |
201,615 |
|
|
|
|
|
|
|
|
Equity in earnings of affiliates |
|
|
|
|
|
|
|
|
Mineral exploration |
|
$ |
2,497 |
|
|
$ |
1,491 |
|
|
|
|
|
|
|
|
Income before income taxes |
|
|
|
|
|
|
|
|
Water infrastructure |
|
$ |
9,189 |
|
|
$ |
11,834 |
|
Mineral exploration |
|
|
11,636 |
|
|
|
5,751 |
|
Energy |
|
|
4,476 |
|
|
|
3,819 |
|
Other |
|
|
20 |
|
|
|
224 |
|
Unallocated corporate expenses |
|
|
(5,851 |
) |
|
|
(5,379 |
) |
Interest |
|
|
(941 |
) |
|
|
(2,430 |
) |
|
|
|
|
|
|
|
Total income before income taxes |
|
$ |
18,529 |
|
|
$ |
13,819 |
|
|
|
|
|
|
|
|
Revenues for the three months ended April 30, 2008 increased $42,929,000, or 21.3%, to $244,544,000
compared to $201,615,000 for the same period last year. Revenues were up across all primary
divisions. A further discussion of results of operations by division is presented below.
Selling, general and administrative expenses increased 12.4% to $33,044,000 for the three months
ended April 30, 2008 compared to $29,408,000 for the same period last year. The increase was
primarily the result of $1,660,000 in expenses added from the acquisitions of Tierdael and SolmeteX
and from wage and benefit increases of $2,179,000.
Equity in earnings of affiliates increased 67.5% to $2,497,000 for the three months ended April 30,
2008 from $1,491,000 for the same period last year. The increase reflects continued strong
performance in the mineral exploration division by our affiliates in Latin America, particularly in
Chile.
Depreciation, depletion and amortization increased 20.3% to $12,441,000 for the three months ended
April 30, 2008 compared to $10,338,000 for the same period last year. The increase was primarily
the result of increased depletion expense of $579,000 resulting from the increase in production of
unconventional gas from the Companys energy operations and additional depreciation from property
additions in the other divisions.
Interest expense decreased to $941,000 for the three months ended April 30, 2008 compared to
$2,430,000 for the same period last year. The decrease was a result of debt paid off with proceeds
of the Companys stock offerings in October 2007.
Income tax expense of $7,967,000 (an effective rate of 43.0%) was recorded for the three months
ended April 30, 2008, compared to $5,666,000 (an effective rate of 41.0%) for the same period last
year. The difference in the effective rate is primarily attributable to the resolution of certain
tax contingencies reflected in the prior year. The effective rate in excess of the statutory
federal rate for the periods was due primarily to the impact of nondeductible expenses and the tax
treatment of certain foreign operations.
18
Water Infrastructure Division
(in thousands)
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
April 30, |
|
|
2008 |
|
2007 |
Revenues |
|
$ |
180,572 |
|
|
$ |
153,509 |
|
Income before income taxes |
|
|
9,189 |
|
|
|
11,834 |
|
Water infrastructure revenues increased 17.6% to $180,572,000 for the three months ended April 30,
2008, from $153,509,000 for the same period last year. The increase in revenues was primarily
attributable to additional revenues of $6,348,000 from the Companys acquisitions of Tierdael and
SolmeteX, and an increase in sewer rehabilitation revenues of $6,629,000 with the balance of
revenue increases spread throughout the group.
Income before income taxes for the water infrastructure division decreased 22.4% to $9,189,000 for
the three months ended April 30, 2008, compared to $11,834,000 for the same period last year.
Included in last years income before income taxes was $1,626,000 in non-recurring recovery of
previously written off costs associated with a ground water transfer project in Texas. Excluding
this item, the 10% decrease in earnings was primarily the result of exceptional rains in the
Midwest and heavy snows in the West which slowed productivity on several projects and increased
fuel and steel costs which, in some cases, could not be passed on to the customers.
The backlog in the water infrastructure division was $370,742,000 as of April 30, 2008, compared to
$336,915,000 as of April 30, 2007.
Mineral Exploration Division
(in thousands)
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
April 30, |
|
|
2008 |
|
2007 |
Revenues |
|
$ |
51,094 |
|
|
$ |
37,097 |
|
Income before income taxes |
|
|
11,636 |
|
|
|
5,751 |
|
Mineral exploration revenues increased 37.7% to $51,094,000 for the three months ended April 30,
2008 from $37,097,000 for the same period last year. The increase was primarily attributable to
continued strength in the Companys markets due to relatively high gold and base metal prices.
Income before income taxes for the mineral exploration division was up 102.3% to $11,636,000 for
the three months ended April 30, 2008, compared to $5,751,000 for the same period last year. The
improved earnings in the division were primarily attributable to the impact of strong incremental
earnings from exploration activity in the Companys African and Australian markets and an increase
of $1,006,000 in equity earnings of affiliates in Latin America.
Energy Division
(in thousands)
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
April 30, |
|
|
2008 |
|
2007 |
Revenues |
|
$ |
11,879 |
|
|
$ |
9,552 |
|
Income before income taxes |
|
|
4,476 |
|
|
|
3,819 |
|
Energy revenues increased 24.4% to $11,879,000 for the three months ended April 30, 2008, compared
to revenues of $9,552,000 for the same period last year. The increase in revenues was attributable
to both increased production from the Companys unconventional gas properties and higher gas
pricing in the Companys market.
Income before income taxes for the energy division was $4,476,000 for the three months ended April
30, 2008, compared to $3,819,000 for the same period last year. The increase in income before
income taxes is due to the increases in production and pricing noted above.
Unallocated Corporate Expenses
Corporate expenses not allocated to individual divisions, primarily included in selling, general
and administrative expenses, were $5,851,000 and $5,379,000 for the three months ended April 30,
2008 and 2007, respectively. The increase for the quarter was primarily due to wage and benefit
increases of $465,000.
19
Changes in Financial Condition
Management exercises discretion regarding the liquidity and capital resource needs of its business
segments. This includes the ability to prioritize the use of capital and debt capacity, to
determine cash management policies and to make decisions regarding capital expenditures.
The Company maintains an agreement (the Master Shelf Agreement) whereby it has $105,000,000 of
unsecured notes available to be issued before September 15, 2009. At April 30, 2008, the Company
had $60,000,000 in notes outstanding under the Master Shelf Agreement. Additionally, the Company
holds a revolving credit facility (the Credit Agreement) composed of an unsecured $200,000,000
revolving facility, less any outstanding letter of credit commitments (which are subject to a
$30,000,000 sublimit). At April 30, 2008, the Company had no borrowings outstanding under the
Credit Agreement (see Note 4 of the Notes to Consolidated Financial Statements). The Company was
in compliance with its financial covenants at April 30, 2008 and expects to remain in compliance
through the foreseeable future.
The Companys working capital as of April 30, 2008 and April 30, 2007 was $134,045,000 and
$88,094,000, respectively, the primary difference being remaining proceeds from the Companys
October 2007 stock offering. The Company believes it will have sufficient cash from operations and
access to credit facilities to meet the Companys operating cash requirements and to fund its
budgeted capital expenditures for fiscal 2009.
Operating Activities
Cash used in operating
activities was $4,010,000 for the three months ended April 30, 2008 as
compared to cash provided by operating activities of $8,512,000 for the three months ended April
30, 2007. The change was primarily due to additional working capital needs due to increased business volume.
Investing Activities
The Companys capital expenditures, net of disposals, of $15,484,000 for the three months ended
April 30, 2008, were split between $8,656,000 to maintain and upgrade its construction equipment
and $6,828,000 toward the Companys expansion into unconventional gas exploration and production,
including the construction of gas pipeline infrastructure near the Companys development projects.
Financing Activities
For the three months ended April 30, 2008, the Company had no incremental borrowings under its
credit facilities.
The Companys contractual obligations and commercial commitments as of April 30, 2008, are
summarized as follows (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Payments/Expiration by Period |
|
|
|
|
|
|
|
Less than |
|
|
|
|
|
|
|
|
|
|
More than |
|
|
|
Total |
|
|
1 year |
|
|
1-3 years |
|
|
4-5 years |
|
|
5 years |
|
Contractual obligations and other
commercial commitments |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Senior Notes |
|
$ |
60,000 |
|
|
$ |
13,333 |
|
|
$ |
40,000 |
|
|
$ |
6,667 |
|
|
$ |
|
|
Credit Agreement |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest payments |
|
|
9,136 |
|
|
|
3,500 |
|
|
|
5,186 |
|
|
|
450 |
|
|
|
|
|
Operating leases |
|
|
38,757 |
|
|
|
10,456 |
|
|
|
15,230 |
|
|
|
9,305 |
|
|
|
3,766 |
|
Mineral interest obligations |
|
|
628 |
|
|
|
110 |
|
|
|
352 |
|
|
|
150 |
|
|
|
16 |
|
Income tax uncertainties |
|
|
1,200 |
|
|
|
1,200 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total contractual obligations |
|
|
109,721 |
|
|
|
28,599 |
|
|
|
60,768 |
|
|
|
16,572 |
|
|
|
3,782 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Standby letters of credit |
|
|
11,716 |
|
|
|
11,716 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Asset retirement obligations |
|
|
1,058 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,058 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total contractual obligations
and commercial commitments |
|
$ |
122,495 |
|
|
$ |
40,315 |
|
|
$ |
60,768 |
|
|
$ |
16,572 |
|
|
$ |
4,840 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The Company expects to meet its contractual cash obligations in the ordinary course of operations,
and that the standby letters of credit will be renewed in connection with its annual insurance
renewal process. Interest is payable on the Senior Notes at fixed interest rates of 6.05% and
5.40%. Interest is payable on the Credit Agreement at variable interest rates equal to, at the
Companys option, a LIBOR rate plus 0.75% to 2.00%, or a base rate, as defined in the Credit
Agreement plus up to 0.50%, depending on the Companys leverage ratio (See Note 4 of the Notes to
Consolidated Financial Statements). Interest payments have been included in the table above based
only on outstanding balances and interest rates as of April 30,
20
2008.
The Company has income tax uncertainties of $6,577,000 at April 30, 2008, that are classified as
non-concurrent on the Companys balance sheet as resolution of these matters is expected to take
more than a year. The ultimate timing of resolutions of these items is uncertain, and accordingly
the amounts have not been included in the table above.
The Company incurs additional obligations in the ordinary course of operations. These obligations,
including but not limited to, income tax payments and pension fundings are expected to be met in
the normal course of operations.
Critical Accounting Policies and Estimates
Managements Discussion and Analysis of Financial Condition and Results of Operations discusses the
Companys consolidated financial statements, which have been prepared in accordance with accounting
principles generally accepted in the United States. The preparation of these financial statements
requires management to make estimates and assumptions that affect the reported amounts of assets
and liabilities and the disclosure of contingent assets and liabilities at the date of the
financial statements and the reported amounts of revenues and expenses during the reporting period.
On an on-going basis, management evaluates its estimates and judgments, which are based on
historical experience and on various other factors that are believed to be reasonable under the
circumstances, the results of which form the basis for making judgments about the carrying values
of assets and liabilities that are not readily apparent from other sources. Actual results may
differ from these estimates under different assumptions or conditions.
Our accounting policies are more fully described in Note 1 of the Notes to Consolidated Financial
Statements, located in Item 1 of this Form 10-Q. We believe that the following represent our more
critical estimates and assumptions used in the preparation of our consolidated financial
statements, although not all inclusive.
Revenue Recognition Revenues are recognized on large, long-term construction contracts meeting
the criteria of Statement of Position 81-1, Accounting for Performance of Construction-Type and
Certain Production-Type Contracts (SOP 81-1), using the percentage-of-completion method based
upon the ratio of costs incurred to total estimated costs at completion. Contract price and cost
estimates are reviewed periodically as work progresses and adjustments proportionate to the
percentage of completion are reflected in contract revenues in the reporting period when such
estimates are revised. Changes in job performance, job conditions and estimated profitability,
including those arising from contract penalty provisions, change orders and final contract
settlements may result in revisions to costs and income and are recognized in the period in which
the revisions are determined. As allowed by SOP 81-1, revenue is recognized on smaller, short-term
construction contracts using the completed contract method. Provisions for estimated losses on
uncompleted construction contracts are made in the period in which such losses are determined.
Revenues for direct sales of equipment and other ancillary products not provided in conjunction
with the performance of construction contracts are recognized at the date of delivery to, and
acceptance by, the customer. Provisions for estimated warranty obligations are made in the period
in which the sales occur.
Contracts for the Companys mineral exploration drilling services are billable based on the
quantity of drilling performed. Thus, revenues for these drilling contracts are recognized on the
basis of actual footage or meterage drilled.
Revenues for the sale of oil and gas by the Companys energy division are recognized on the basis
of volumes sold at the time of delivery to an end user or an interstate pipeline, net of amounts
attributable to royalty or working interest holders.
The Companys revenues are presented net of taxes imposed on revenue-producing transactions with
its customers, such as, but not limited to, sales, use, value-added, and some excise taxes.
Oil and gas properties and mineral interests The Company follows the full-cost method of
accounting for oil and gas properties. Under this method, all productive and nonproductive costs
incurred in connection with the exploration for and development of oil and gas reserves are
capitalized. Such capitalized costs include lease acquisition, geological and geophysical work,
delay rentals, drilling, completing and equipping oil and gas wells, and salaries, benefits and
other internal salary-related
costs directly attributable to these activities. Costs associated with production and general
corporate activities are expensed in the period incurred. Normal dispositions of oil and gas
properties are accounted for as adjustments of capitalized costs, with no gain or loss recognized.
Separate full-cost pools are established for each country in which the Company has exploration
activities.
The Company is required to review the carrying value of its oil and gas properties each quarter
under the full cost accounting rules of the SEC. Under these rules, capitalized costs of proved
oil and gas properties, as adjusted for asset retirement
21
obligations, may not exceed the present
value of estimated future net revenues from proved reserves, discounted at 10%. Application of the
ceiling test generally requires pricing future revenues at the unescalated prices in effect as of
the last day of the period, with effect given to the Companys fixed-price physical delivery
contracts, and requires a write-down for accounting purposes if the ceiling is exceeded. Unproved
oil and gas properties are not amortized, but are assessed for impairment either individually or on
an aggregated basis using a comparison of the carrying values of the unproved properties to net
future cash flows.
Reserve Estimates The Companys estimates of natural gas reserves, by necessity, are projections
based on geologic and engineering data, and there are uncertainties inherent in the interpretation
of such data as well as the projection of future rates of production and the timing of development
expenditures. Reserve engineering is a subjective process of estimating underground accumulations
of gas that are difficult to measure. The accuracy of any reserve estimate is a function of the
quality of available data, engineering and geological interpretation and judgment. Estimates of
economically recoverable gas reserves and future net cash flows necessarily depend upon a number of
variable factors and assumptions, such as historical production from the area compared with
production from other producing areas, the assumed effects of regulations by governmental agencies
and assumptions governing natural gas prices, future operating costs, severance, ad valorem and
excise taxes, development costs and workover and remedial costs, all of which may in fact vary
considerably from actual results. For these reasons, estimates of the economically recoverable
quantities of gas attributable to any particular group of properties, classifications of such
reserves based on risk of recovery, and estimates of the future net cash flows expected there from
may vary substantially. Any significant variance in the assumptions could materially affect the
estimated quantity and value of the reserves, which could affect the carrying value of the
Companys oil and gas properties and the rate of depletion of the oil and gas properties. Actual
production, revenues and expenditures with respect to the Companys reserves will likely vary from
estimates, and such variances may be material.
Goodwill and Other Intangibles The Company accounts for goodwill and other intangible assets in
accordance with the Statement of Financial Accounting Standards No. 142, Goodwill and Other
Intangible Assets. Other intangible assets primarily consist of trademarks, customer-related
intangible assets and patents obtained through business acquisitions. Amortizable intangible
assets are being amortized over their estimated useful lives, which range from two to 40 years.
The impairment evaluation for goodwill is conducted annually, or more frequently, if events or
changes in circumstances indicate that an asset might be impaired. The evaluation is performed by
using a two-step process. In the first step, the fair value of each reporting unit is compared with
the carrying amount of the reporting unit, including goodwill. The estimated fair value of the
reporting unit is generally determined on the basis of discounted future cash flows. If the
estimated fair value of the reporting unit is less than the carrying amount of the reporting unit,
then a second step must be completed in order to determine the amount of the goodwill impairment
that should be recorded. In the second step, the implied fair value of the reporting units
goodwill is determined by allocating the reporting units fair value to all of its assets and
liabilities other than goodwill (including any unrecognized intangible assets) in a manner similar
to a purchase price allocation. The resulting implied fair value of the goodwill that results from
the application of this second step is then compared to the carrying amount of the goodwill and an
impairment charge is recorded for the difference.
The impairment evaluation of the carrying amount of intangible assets with indefinite lives is
conducted annually or more frequently if events or changes in circumstances indicate that an asset
might be impaired. The evaluation is performed by comparing the carrying amount of these assets to
their estimated fair value. If the estimated fair value is less than the carrying amount of the
intangible assets with indefinite lives, then an impairment charge is recorded to reduce the asset
to its estimated fair value. The estimated fair value is generally determined on the basis of
discounted future cash flows.
The assumptions used in the estimate of fair value are generally consistent with the past
performance of each reporting unit and are also consistent with the projections and assumptions
that are used in current operating plans. Such assumptions are subject to change as a result of
changing economic and competitive conditions.
Other Long-lived Assets In the event of an indication of possible impairment, the Company
evaluates the fair value and future benefits of long-lived assets, including the Companys gas
transportation facilities and equipment, by performing an analysis of the anticipated future net
cash flows of the related long-lived assets and reducing their carrying value by the excess, if
any, of the result of such calculation. The Company believes at this time that the carrying values
and useful lives of its long-lived assets continue to be appropriate.
Accrued Insurance Expense The Company maintains insurance programs where it is responsible for a
certain amount of each claim up to a self-insured limit. Estimates are recorded for health and
welfare, property and casualty insurance costs that are associated with these programs. These
costs are estimated based on actuarially determined projections of future payments under these
programs. Should a greater amount of claims occur compared to what was estimated or medical costs
increase beyond what was anticipated, reserves recorded may not be sufficient and additional costs
to the consolidated financial statements could be required.
22
Costs estimated to be incurred in the future for employee medical benefits, property, workers
compensation and casualty insurance programs resulting from claims which have occurred are accrued
currently. Under the terms of the Companys agreement with the various insurance carriers
administering these claims, the Company is not required to remit the total premium until the claims
are actually paid by the insurance companies. These costs are not expected to significantly impact
liquidity in future periods.
Income Taxes Income taxes are provided using the asset/liability method, in which deferred taxes
are recognized for the tax consequences of temporary differences between the financial statement
carrying amounts and tax bases of existing assets and liabilities. Deferred tax assets are
reviewed for recoverability and valuation allowances are provided as necessary. Provision for U.S.
income taxes on undistributed earnings of foreign subsidiaries and affiliates is made only on those
amounts in excess of funds considered to be invested indefinitely. In general, the Company records
income tax expense during interim periods based on its best estimate of the full years effective
tax rate. However, income tax expense relating to adjustments to the Companys liabilities for FIN
48, Accounting for Uncertainty in Income Taxes, an interpretation of FASB statement 109
(FIN48), is accounted for discretely in the interim period in which it occurs.
Litigation and Other Contingencies The Company is involved in litigation incidental to its
business, the disposition of which is not expected to have a material effect on the Companys
financial position or results of operations. It is possible, however, that future results of
operations for any particular quarterly or annual period could be materially affected by changes in
the Companys assumptions related to these proceedings. The Company accrues its best estimate of
the probable cost for the resolution of legal claims. Such estimates are developed in consultation
with outside counsel handling these matters and are based upon a combination of litigation and
settlement strategies. To the extent additional information arises or the Companys strategies
change, it is possible that the Companys estimate of its probable liability in these matters may
change.
ITEM 3. Quantitative and Qualitative Disclosures About Market Risk
The principal market risks to which the Company is exposed are interest rates on variable rate
debt, foreign exchange rates giving rise to translation and transaction gains and losses and
fluctuations in the price of natural gas.
The Company centrally manages its debt portfolio considering overall financing strategies and tax
consequences. A description of the Companys debt is in Note 11 of the Notes to Consolidated
Financial Statements appearing in the Companys January 31, 2008 Form 10-K and Note 4 of this Form
10-Q. As of April 30, 2008, an instantaneous change in interest rates of one percentage point
would not change the Companys annual interest expense, as we have no variable rate debt
outstanding.
Operating in international markets involves exposure to possible volatile movements in currency
exchange rates. Currently, the Companys primary international operations are in Australia, Africa,
Mexico and Italy. The Companys affiliates also operate in South America and Mexico. The operations
are described in Notes l and 3 of the Notes to Consolidated Financial Statements appearing in the
Companys January 31, 2008 Form 10-K and Note 9 of this Form 10-Q. The majority of the Companys
contracts in Africa and Mexico are U.S. dollar based, providing a natural reduction in exposure to
currency fluctuations. The Company also may utilize various hedge instruments, primarily foreign
currency option contracts, to manage the exposures associated with fluctuating currency exchange
rates. As of April 30, 2008, the Company held no such hedge instruments.
As currency exchange rates change, translation of the income statements of the Companys
international operations into U.S. dollars may affect year-to-year comparability of operating
results. We estimate that a ten percent change in foreign exchange rates would not have
significantly impacted income before income taxes for the three months ended April 30, 2008. This
quantitative measure has inherent limitations, as it does not take into account any governmental
actions, changes in customer purchasing patterns or changes in the Companys financing and
operating strategies.
The Company is also exposed to fluctuations in the price of natural gas, which result from the sale
of the energy divisions unconventional gas production. The price of natural gas is volatile and
the Company has entered into fixed-price physical contracts covering a portion of its production to
manage price fluctuations and to achieve a more predictable cash flow. As of April 30, 2008, the
Company held contracts for physical delivery of 8,400,000 million British Thermal Units (MMBtu)
of natural gas through March 2010 at prices ranging from $7.82 to $8.73 per MMBtu through March
2009 and from $7.82 to $9.13 per MMBtu from April 2009 to March 2010. The estimated fair value of
such contracts at April 30, 2008 was a loss of $4,929,000. The Company generally intends to
maintain contracts in place to cover 50% to 75% of its production. We estimate that a ten percent
change in the price of natural gas would have impacted income before income taxes by approximately
$450,000 for the three months ended April 30, 2008.
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ITEM 4. Controls and Procedures
Based on an evaluation of disclosure controls and procedures for the period ended April 30, 2008,
conducted under the supervision and with the participation of the Companys management, including
the Principal Executive Officer and the Principal Financial Officer, the Company concluded that its
disclosure controls and procedures are effective to ensure that information required to be
disclosed by the Company in reports that it files or submits under the Securities Exchange Act of
1934 is accumulated and communicated to the Companys management (including the Principal Executive
Officer and the Principal Financial Officer) to allow timely decisions regarding required
disclosure, and is recorded, processed, summarized and reported within the time periods specified
in Securities and Exchange Commission rules and forms.
Based on an evaluation of internal controls over financial reporting conducted under the
supervision and the participation of the Companys management, including the Principal Executive
Officer and the Principal Financial Officer, for the period ended April 30, 2008, the Company
concluded that its internal control over financial reporting is effective as of April 30, 2008. The
Company has not made any significant changes in internal controls or in other factors that could
significantly affect internal controls since such evaluation.
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PART II
ITEM 1 Legal Proceedings
On April 30, 2008, Levelland/Hockley County Ethanol, LLC (Levelland) filed a Complaint against
the Company in the District Court for Hockley County, Texas. On May 28, 2008, the Company removed
the case to the United States District Court for the Northern District of Texas, Lubbock Division.
On June 2, 2008, Levelland filed a First Amended Complaint against the Company in the Federal
District Court for the Northern District of Texas, Lubbock Division. Levelland owns an ethanol
plant located in Levelland, Texas. In July 2007, Levelland entered into a lease agreement with the
Company for certain water treatment equipment for the ethanol plant. Levelland alleges that the
equipment leased from the Company fails to treat the water coming into the ethanol plant to
required levels. The First Amended Complaint seeks damages for breach of contract, breach of
warranty, violation of the Texas Deceptive Trade Practices Act, negligence, negligent
misrepresentation and fraud, in connection with the design and construction of the water treatment
facility. The Company believes that it has meritorious defenses to the claims and intends to
vigorously defend against them.
ITEM 2 Changes in Securities
NOT APPLICABLE
ITEM 3 Defaults Upon Senior Securities
NOT APPLICABLE
ITEM 4 Submission of Matters to a Vote of Security Holders
NONE
ITEM 5 Other Information
NONE
ITEM 6 Exhibits and Reports on Form 8-K
a) Exhibits
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31(1)
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Section 302 Certification of Chief Executive Officer of the Company. |
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31(2)
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Section 302 Certification of Chief Financial Officer of the Company. |
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32(1)
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Section 906 Certification of Chief Executive Officer of the Company. |
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32(2)
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Section 906 Certification of Chief Financial Officer of the Company. |
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b) |
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Reports on Form 8-K |
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Form 8-K filed on April 9, 2008, related to the Companys fiscal year ended January 31,
2008 earnings press release. |
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Form 8-K filed on March 19, 2008, related to severance agreements entered into between
the Company and certain of its executive officers. |
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Form 8-K filed on February 11, 2008, related to the Companys Amended and Restated
Executive Incentive Compensation Plan (the Plan) and disclosing the Companys goals to earn
bonuses under the plan for fiscal 2009. |
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* * * * * * * * * *
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused
this report to be signed on its behalf by the undersigned thereunto duly authorized.
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Layne Christensen Company |
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(Registrant)
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DATE: June 9, 2008 |
/s/ A.B. Schmitt
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A.B. Schmitt, President |
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and Chief Executive Officer |
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DATE: June 9, 2008 |
/s/ Jerry W. Fanska
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Jerry W. Fanska, Sr. Vice President |
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Finance and Treasurer |
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26