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(Mark One) |
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x |
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
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For the quarterly period ended October 31, 2012 |
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OR |
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o |
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
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For the transition period from _________ to _________ |
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Commission File Number 001-09097 |
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REX AMERICAN RESOURCES CORPORATION |
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(Exact name of registrant as specified in its charter) |
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Delaware |
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31-1095548 |
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(State or other jurisdiction of |
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(I.R.S. Employer |
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incorporation or organization) |
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Identification Number) |
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2875 Needmore Road, Dayton, Ohio |
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45414 |
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(Address of principal executive offices) |
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(Zip Code) |
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(937) 276-3931
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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 x No o
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).
Yes x No o
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Large accelerated filer o |
Accelerated filer x |
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Non-accelerated filer o (Do not check if a smaller reporting company) |
Smaller reporting company o |
Indicate by
check mark whether the registrant is a shell company (as defined in Rule 12b-2
of the Exchange Act).
Yes
o
No
x
At the close of business on December 5, 2012 the registrant had 8,157,254 shares of Common Stock, par value $.01 per share, outstanding.
REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
INDEX
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3 |
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4 |
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5 |
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6 |
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7 |
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Management’s Discussion and Analysis of Financial Condition and Results of Operations |
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26 |
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43 |
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45 |
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45 |
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46 |
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46 |
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46 |
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46 |
2
P ART I. FINANCIAL INFORMATION
REX
AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
C
onsolidated Condensed Balance Sheets
Unaudited
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October 31,
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January 31,
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(In Thousands) |
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Assets |
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Current assets: |
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Cash and cash equivalents |
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$ |
68,105 |
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$ |
75,013 |
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Accounts receivable |
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17,765 |
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12,784 |
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Inventories |
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28,304 |
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30,349 |
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Refundable income taxes |
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895 |
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1,816 |
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Prepaid expenses and other |
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4,335 |
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3,987 |
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Deferred taxes, net |
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2,530 |
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3,090 |
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Total current assets |
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121,934 |
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127,039 |
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Property and equipment, net |
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227,811 |
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240,084 |
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Other assets |
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6,793 |
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7,884 |
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Equity method investments |
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61,072 |
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61,679 |
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Restricted investments and deposits |
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503 |
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1,363 |
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Total assets |
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$ |
418,113 |
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$ |
438,049 |
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Liabilities and equity: |
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Current liabilities: |
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Current portion of long-term debt, alternative energy |
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$ |
12,567 |
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$ |
14,972 |
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Current portion of long-term debt, other |
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267 |
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250 |
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Accounts payable, trade |
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10,108 |
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6,985 |
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Deferred income |
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950 |
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1,864 |
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Accrued real estate taxes |
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1,310 |
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2,750 |
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Accrued payroll and related items |
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740 |
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2,882 |
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Derivative financial instruments |
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1,843 |
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1,694 |
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Other current liabilities |
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5,029 |
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5,844 |
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Total current liabilities |
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32,814 |
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37,241 |
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Long-term liabilities: |
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Long-term debt, alternative energy |
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95,117 |
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107,706 |
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Long-term debt, other |
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619 |
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821 |
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Deferred taxes |
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5,201 |
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4,642 |
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Deferred income |
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250 |
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552 |
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Derivative financial instruments |
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1,383 |
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2,541 |
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Other long-term liabilities |
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2,530 |
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2,703 |
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Total long-term liabilities |
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105,100 |
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118,965 |
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Equity: |
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REX shareholders’ equity: |
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Common stock |
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299 |
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299 |
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Paid-in capital |
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143,667 |
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142,994 |
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Retained earnings |
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326,471 |
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324,323 |
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Treasury stock |
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(219,011 |
) |
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(215,105 |
) |
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Total REX shareholders’ equity |
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251,426 |
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252,511 |
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Noncontrolling interests |
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28,773 |
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29,332 |
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Total equity |
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280,199 |
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281,843 |
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Total liabilities and equity |
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$ |
418,113 |
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$ |
438,049 |
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The accompanying notes are an integral part of these unaudited consolidated condensed financial statements.
3
REX
AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
C
onsolidated Condensed Statements Of Operations
Unaudited
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Three Months
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Nine Months
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2012 |
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2011 |
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2012 |
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2011 |
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(In Thousands, Except Per Share Amounts) |
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Net sales and revenue |
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$ |
178,950 |
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$ |
84,524 |
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$ |
483,122 |
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$ |
239,483 |
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Cost of sales |
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175,303 |
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75,506 |
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467,015 |
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225,960 |
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Gross profit |
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3,647 |
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9,018 |
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16,107 |
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13,523 |
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Selling, general and administrative expenses |
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(2,995 |
) |
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(2,344 |
) |
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(9,190 |
) |
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(6,616 |
) |
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Equity in income of unconsolidated affiliates |
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1,542 |
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6,284 |
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1,503 |
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15,827 |
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Income from synthetic fuel investments |
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— |
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— |
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— |
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2,883 |
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Interest income |
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42 |
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92 |
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132 |
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364 |
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Interest expense |
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(1,206 |
) |
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(620 |
) |
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(3,733 |
) |
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(1,923 |
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Losses on derivative financial instruments, net |
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(140 |
) |
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(501 |
) |
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(366 |
) |
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(1,190 |
) |
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Income from continuing operations before income taxes |
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890 |
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11,929 |
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4,453 |
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22,868 |
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Provision for income taxes |
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(134 |
) |
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(4,055 |
) |
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(1,220 |
) |
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(8,233 |
) |
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Income from continuing operations |
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756 |
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7,874 |
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3,233 |
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14,635 |
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Income from discontinued operations, net of tax |
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107 |
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186 |
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361 |
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856 |
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Gain on disposal of discontinued operations, net of tax |
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30 |
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267 |
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80 |
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425 |
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Net income |
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893 |
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8,327 |
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3,674 |
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15,916 |
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Net income attributable to noncontrolling interests |
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(484 |
) |
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(1,845 |
) |
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(1,526 |
) |
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(2,435 |
) |
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Net income attributable to REX common shareholders |
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$ |
409 |
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$ |
6,482 |
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$ |
2,148 |
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$ |
13,481 |
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Weighted average shares outstanding – basic |
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8,226 |
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9,205 |
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8,311 |
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9,385 |
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Basic income per share from continuing operations attributable to REX common shareholders |
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$ |
0.03 |
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$ |
0.65 |
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$ |
0.21 |
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$ |
1.30 |
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Basic income per share from discontinued operations attributable to REX common shareholders |
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0.01 |
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0.02 |
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0.04 |
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0.09 |
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Basic income per share on disposal of discontinued operations attributable to REX common shareholders |
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0.01 |
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0.03 |
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0.01 |
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0.05 |
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Basic net income per share attributable to REX common shareholders |
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$ |
0.05 |
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$ |
0.70 |
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$ |
0.26 |
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$ |
1.44 |
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Weighted average shares outstanding – diluted |
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8,258 |
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9,239 |
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8,361 |
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9,453 |
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Diluted income per share from continuing operations attributable to REX common shareholders |
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$ |
0.03 |
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$ |
0.65 |
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$ |
0.21 |
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$ |
1.29 |
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Diluted income per share from discontinued operations attributable to REX common shareholders |
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0.01 |
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0.02 |
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0.04 |
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0.09 |
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Diluted income per share on disposal of discontinued operations attributable to REX common shareholders |
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0.01 |
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0.03 |
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|
0.01 |
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0.05 |
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Diluted net income per share attributable to REX common shareholders |
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$ |
0.05 |
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$ |
0.70 |
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$ |
0.26 |
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$ |
1.43 |
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Amounts attributable to REX common shareholders: |
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Income from continuing operations, net of tax |
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$ |
272 |
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$ |
6,029 |
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$ |
1,707 |
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$ |
12,200 |
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Income from discontinued operations, net of tax |
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|
137 |
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|
453 |
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|
441 |
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1,281 |
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Net income |
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$ |
409 |
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$ |
6,482 |
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$ |
2,148 |
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$ |
13,481 |
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The accompanying notes are an integral part of these unaudited consolidated condensed financial statements.
4
REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
C
onsolidated Condensed Statements Of Equity
Unaudited
(In Thousands)
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REX Shareholders |
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Common
Shares
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Treasury |
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Paid-in
|
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Retained
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Noncontrolling
|
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Total
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Shares |
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Amount |
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Shares |
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Amount |
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Balance at January 31, 2012 |
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|
29,853 |
|
$ |
299 |
|
|
21,523 |
|
$ |
(215,105 |
) |
$ |
142,994 |
|
$ |
324,323 |
|
$ |
29,332 |
|
$ |
281,843 |
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,148 |
|
|
1,526 |
|
|
3,674 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Treasury stock acquired |
|
|
|
|
|
|
|
|
246 |
|
|
(4,905 |
) |
|
|
|
|
|
|
|
|
|
|
(4,905 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Noncontrolling interests distribution and other |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(2,085 |
) |
|
(2,085 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock options and related tax effects |
|
|
— |
|
|
— |
|
|
(99 |
) |
|
999 |
|
|
673 |
|
|
— |
|
|
— |
|
|
1,672 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at October 31, 2012 |
|
|
29,853 |
|
$ |
299 |
|
|
21,670 |
|
$ |
(219,011 |
) |
$ |
143,667 |
|
$ |
326,471 |
|
$ |
28,773 |
|
$ |
280,199 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common
Shares
|
|
Treasury |
|
Paid-in
|
|
Retained
|
|
Noncontrolling
|
|
Total
|
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||
|
|
|
Shares |
|
Amount |
|
Shares |
|
Amount |
|
|
|
|
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||
|
|
|||||||||||||||||||||||||
|
Balance at January 31, 2011 |
|
|
29,853 |
|
$ |
299 |
|
|
20,461 |
|
$ |
(193,713 |
) |
$ |
142,293 |
|
$ |
296,053 |
|
$ |
25,032 |
|
$ |
269,964 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
13,481 |
|
|
2,435 |
|
|
15,916 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Treasury stock acquired |
|
|
|
|
|
|
|
|
1,451 |
|
|
(24,410 |
) |
|
|
|
|
|
|
|
|
|
|
(24,410 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Noncontrolling interests distribution and other |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,988 |
) |
|
(1,988 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock options and related tax effects |
|
|
— |
|
|
— |
|
|
(436 |
) |
|
4,066 |
|
|
86 |
|
|
— |
|
|
— |
|
|
4,152 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at October 31, 2011 |
|
|
29,853 |
|
$ |
299 |
|
|
21,476 |
|
$ |
(214,057 |
) |
$ |
142,379 |
|
$ |
309,534 |
|
$ |
25,479 |
|
$ |
263,634 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of these unaudited consolidated condensed financial statements.
5
REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
C
onsolidated Condensed Statements Of Cash Flows
Unaudited
|
|
|
|
|
|
|
|
|
|
|
|
Nine
Months Ended
|
|
||||
|
|
|
|
|
||||
|
|
|
2012 |
|
2011 |
|
||
|
|
|
|
|
|
|
||
|
|
|
(In Thousands) |
|
||||
|
Cash flows from operating activities: |
|
|
|
|
|
|
|
|
Net income including noncontrolling interests |
|
$ |
3,674 |
|
$ |
15,916 |
|
|
Adjustments to reconcile net income to net cash provided by operating activities: |
|
|
|
|
|
|
|
|
Depreciation and amortization |
|
|
12,430 |
|
|
8,206 |
|
|
Impairment charges |
|
|
279 |
|
|
1,164 |
|
|
Income from equity method investments |
|
|
(1,503 |
) |
|
(15,827 |
) |
|
Income from synthetic fuel investments |
|
|
— |
|
|
(2,883 |
) |
|
Loss (gain) on disposal of real estate and property and equipment |
|
|
424 |
|
|
(634 |
) |
|
Dividends received from equity method investees |
|
|
2,005 |
|
|
2,316 |
|
|
Deferred income |
|
|
(1,429 |
) |
|
(3,273 |
) |
|
Derivative financial instruments |
|
|
(1,009 |
) |
|
(738 |
) |
|
Deferred income tax |
|
|
1,111 |
|
|
8,177 |
|
|
Changes in assets and liabilities: |
|
|
|
|
|
|
|
|
Accounts receivable |
|
|
(4,981 |
) |
|
2,318 |
|
|
Inventories |
|
|
2,045 |
|
|
(2,266 |
) |
|
Other assets |
|
|
1,513 |
|
|
9,486 |
|
|
Accounts payable, trade |
|
|
3,030 |
|
|
(1,475 |
) |
|
Other liabilities |
|
|
(4,357 |
) |
|
2,031 |
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by operating activities |
|
|
13,232 |
|
|
22,518 |
|
|
|
|
|
|
|
|
|
|
|
Cash flows from investing activities: |
|
|
|
|
|
|
|
|
Capital expenditures |
|
|
(2,533 |
) |
|
(720 |
) |
|
Proceeds from sale of synthetic fuel investment |
|
|
— |
|
|
2,883 |
|
|
Restricted investments |
|
|
860 |
|
|
— |
|
|
Proceeds from sale of real estate and property and equipment |
|
|
2,272 |
|
|
3,436 |
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by investing activities |
|
|
599 |
|
|
5,599 |
|
|
|
|
|
|
|
|
|
|
|
Cash flows from financing activities: |
|
|
|
|
|
|
|
|
Payments of long-term debt |
|
|
(15,179 |
) |
|
(8,160 |
) |
|
Repayments of contingent consideration |
|
|
— |
|
|
(1,313 |
) |
|
Stock options exercised |
|
|
358 |
|
|
317 |
|
|
Noncontrolling interests distribution and other |
|
|
(2,085 |
) |
|
(1,988 |
) |
|
Treasury stock acquired |
|
|
(3,833 |
) |
|
(21,224 |
) |
|
|
|
|
|
|
|
|
|
|
Net cash used in financing activities |
|
|
(20,739 |
) |
|
(32,368 |
) |
|
|
|
|
|
|
|
|
|
|
Net decrease in cash and cash equivalents |
|
|
(6,908 |
) |
|
(4,251 |
) |
|
Cash and cash equivalents, beginning of period |
|
|
75,013 |
|
|
91,019 |
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents, end of period |
|
$ |
68,105 |
|
$ |
86,768 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Non cash financing activities - Cashless exercise of stock options |
|
$ |
1,072 |
|
$ |
3,186 |
|
|
|
|
|
|
|
|
|
|
|
Non cash investing activities - Accrued capital expenditures |
|
$ |
93 |
|
$ |
164 |
|
|
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of these unaudited consolidated condensed financial statements.
6
|
|
|
REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES |
|
|
|
N OTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS |
|
October 31, 2012 |
Note 1.
Consolidated
Condensed Financial Statements
The consolidated condensed financial statements included in this report have been prepared by the Company, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission and include, in the opinion of management, all adjustments necessary to state fairly the information set forth therein. Any such adjustments were of a normal recurring nature. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been omitted pursuant to such rules and regulations, although the Company believes that the disclosures are adequate to make the information presented not misleading. Financial information as of January 31, 2012 included in these financial statements has been derived from the audited consolidated financial statements included in the Company’s Annual Report on Form 10-K for the year ended January 31, 2012 (fiscal year 2011). It is suggested that these unaudited consolidated condensed financial statements be read in conjunction with the consolidated financial statements and the notes thereto included in the Company’s Annual Report on Form 10-K for the year ended January 31, 2012. The results of operations for the interim periods are not necessarily indicative of the results to be expected for the year.
Basis of Consolidation – The consolidated condensed financial statements in this report include the operating results and financial position of REX American Resources Corporation and its wholly and majority owned subsidiaries. The Company includes the results of operations of One Earth Energy, LLC (“One Earth”) in its Consolidated Condensed Statements of Operations on a delayed basis of one month. Effective November 1, 2011, the Company acquired a majority ownership interest in NuGen Energy, LLC (“NuGen”), and have included the results of operations in its Consolidated Condensed Statements of Operations on a prospective basis.
Nature of Operations – The Company operates in two reportable segments, alternative energy and real estate. The Company substantially completed the exit of its retail business during the second quarter of fiscal year 2009, although it continues to recognize revenue and expense associated with administering extended service policies as discontinued operations.
Note 2.
Accounting
Policies
The interim consolidated condensed financial statements have been prepared in accordance with the accounting policies described in the notes to the consolidated financial statements included in the Company’s fiscal year 2011 Annual Report on Form 10-K. While management believes that the procedures followed in the preparation of interim financial information are reasonable, the accuracy of some estimated amounts is dependent upon facts that will exist or calculations that will be accomplished at fiscal year-end. Examples of such estimates include accrued liabilities, such as management bonuses, and the provision for income taxes. Any adjustments pursuant to such estimates during the quarter were of a normal recurring nature. Actual results could differ from those estimates.
7
Revenue Recognition
The Company recognizes sales from the production of ethanol, distillers grains and non-food grade corn oil when title transfers to customers, upon shipment from its plant. Shipping and handling charges to customers are included in net sales and revenue.
The Company includes income from real estate leasing activities in net sales and revenue. The Company accounts for these leases as operating leases. Accordingly, minimum rental revenue is recognized on a straight-line basis over the term of the lease.
The Company sold, prior to its exit of the retail business, extended service policies covering periods beyond the normal manufacturers’ warranty periods, usually with terms of coverage (including manufacturers’ warranty periods) of between 12 to 60 months. Contract revenues and sales commissions are deferred and amortized on a straight-line basis over the life of the contracts after the expiration of applicable manufacturers’ warranty periods. The Company retains the obligation to perform warranty service and such costs are charged to operations as incurred. All related revenue and expense is classified as discontinued operations.
Cost of Sales
Alternative energy cost of sales includes depreciation, costs of raw materials, inbound freight charges, purchasing and receiving costs, inspection costs, shipping costs, other distribution expenses, warehousing costs, plant management, certain compensation costs, and general facility overhead charges.
Real estate cost of sales includes depreciation, real estate taxes, insurance, repairs and maintenance and other costs directly associated with operating the Company’s portfolio of real property.
Selling, General and Administrative Expenses
The Company includes non-production related costs from its alternative energy segment such as professional fees, selling charges and certain payroll in selling, general and administrative expenses.
The Company includes costs not directly related to operating its portfolio of real property from its real estate segment such as certain payroll and related costs, professional fees and other general expenses in selling, general and administrative expenses.
The Company includes costs associated with its corporate headquarters such as certain payroll and related costs, professional fees and other general expenses in selling, general and administrative expenses.
8
Interest Cost
No interest was capitalized for the nine months ended October 31, 2012 and 2011. Cash paid for interest for the three months ended October 31, 2012 and 2011 was approximately $1,044,000 and $645,000, respectively. Cash paid for interest for the nine months ended October 31, 2012 and 2011 was approximately $3,779,000 and $1,998,000, respectively.
Financial Instruments
The Company uses derivative financial instruments to manage its balance of fixed and variable rate debt. The Company does not hold or issue derivative financial instruments for trading or speculative purposes. Interest rate swap agreements involve the exchange of fixed and variable rate interest payments and do not represent an actual exchange of the notional amounts between the parties. The swap agreements were not designated for hedge accounting pursuant to ASC 815, Derivatives and Hedging (“ASC 815”). The interest rate swaps are recorded at their fair values and the changes in fair values are recorded as gain or loss on derivative financial instruments in the Consolidated Condensed Statements of Operations. The Company paid settlements of interest rate swaps of approximately $1,375,000 and $1,928,000 for the nine months ended October 31, 2012 and 2011, respectively.
Forward grain purchase and ethanol and distillers grains sale contracts are accounted for under the “normal purchases and normal sales” scope exemption of ASC 815 because these arrangements are for purchases of grain that will be delivered in quantities expected to be used by the Company and sales of ethanol and distillers grains quantities expected to be produced by the Company over a reasonable period of time in the normal course of business.
Income Taxes
The Company applies an effective tax rate to interim periods that is consistent with the Company’s estimated annual tax rate. The Company provides for deferred tax liabilities and assets for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis and operating loss and tax credit carryforwards. The Company provides for a valuation allowance if, based on the weight of available evidence, it is more likely than not that some or all of the deferred tax assets will not be realized. The Company paid income taxes of approximately $51,000 during the nine months ended October 31, 2012. The Company paid no income taxes during the nine months ended October 31, 2011. The Company received refunds of $1,000,000 and $7,247,000 during the nine months ended October 31, 2012 and 2011, respectively.
As of October 31, 2012, total unrecognized tax benefits were approximately $2,157,000 and accrued penalties and interest were $374,000. If the Company were to prevail on all unrecognized tax benefits recorded, approximately $82,000 of the reserve would benefit the effective tax rate. In addition, the impact of penalties and interest would also benefit the effective tax rate. Interest and penalties associated with unrecognized tax benefits are recorded within income tax expense. On a quarterly and annual basis, the Company accrues for the effects of open uncertain tax positions and the related potential penalties and interest.
9
Inventories
Inventories are carried at the lower of cost or market on a first-in, first-out basis. Alternative energy segment inventory includes direct production costs and certain overhead costs such as depreciation, property taxes and utilities related to producing ethanol and related by-products. Inventory is permanently written down for instances when cost exceeds estimated net realizable value; such write-downs are based primarily upon commodity prices as the market value of inventory is often dependent upon changes in commodity prices. The write-down of inventory was approximately $469,000 and $153,000 at October 31, 2012 and January 31, 2012, respectively. Fluctuations in the write-down of inventory generally relate to the levels and composition of such inventory at a given point in time. The components of inventory at October 31, 2012 and January 31, 2012 are as follows (amounts in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
October 31,
|
|
January 31,
|
|
||
|
|
|
|
|
|
|
||
|
|
|
|
|
|
|
|
|
|
Ethanol and other finished goods |
|
$ |
7,268 |
|
$ |
5,318 |
|
|
Work in process |
|
|
4,576 |
|
|
3,819 |
|
|
Grain and other raw materials |
|
|
16,460 |
|
|
21,212 |
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
28,304 |
|
$ |
30,349 |
|
|
|
|
|
|
|
|
|
|
Property and Equipment
Property and equipment is recorded at cost. Depreciation is computed using the straight-line method. Estimated useful lives are 15 to 40 years for buildings and improvements, and 3 to 20 years for fixtures and equipment.
In accordance with ASC 360-10 “ Impairment or Disposal of Long-Lived Assets” , the carrying value of long-lived assets is assessed for recoverability by management when changes in circumstances indicate that the carrying amount may not be recoverable, based on an analysis of undiscounted future expected cash flows from the use and ultimate disposition of the asset. Impairment charges were insignificant in the three months ended October 31, 2012 and 2011, respectively and were approximately $0.3 million and $1.2 million in the first nine months of fiscal years 2012 and 2011, respectively. These charges relate to the Company’s real estate segment and discontinued operations. Impairment charges result from the Company’s management performing cash flow analysis and represent management’s estimate of the excess of net book value over fair value. Fair value is estimated using expected future cash flows on a discounted basis or appraisals of specific properties as appropriate. Long-lived assets are tested for recoverability whenever events or changes in circumstances indicate that its carrying amount may not be recoverable. Given the nature of the Company’s business, events and changes in circumstances include, but are not limited to, a significant decline in estimated future cash flows, a sustained decline in market prices for similar assets, or a significant adverse change in legal or regulatory factors or the business climate. A significant decline in estimated future cash flows is represented by a greater than 25% annual decline in expected future cash flows (for asset groups in the real estate reportable segment) or a change in the spread between ethanol and grain prices
10
that would result in greater than six consecutive months of estimated or actual significant negative cash flows (for asset groups in the alternative energy reportable segment).
The Company tests for recoverability of an asset group by comparing its carrying amount to its estimated undiscounted future cash flows. If the carrying amount of an asset group exceeds its estimated undiscounted future cash flows, the Company recognizes an impairment charge for the amount by which the asset group’s carrying amount exceeds its fair value, if any. The Company generally determines the fair value of the asset group using a discounted cash flow model based on market participant assumptions (for income producing asset groups) or by obtaining appraisals based on the market approach and comparable market transactions (for non-income producing asset groups).
In the real estate reportable segment, each individual real estate property represents the lowest level for which identifiable cash flows are largely independent of the cash flows of other assets and liabilities. As such, the Company separately tests individual real estate properties for recoverability. The real estate reportable segment includes both income producing and non-income producing asset groups.
In the alternative energy reportable segment, each individual ethanol plant represents the lowest level for which identifiable cash flows are independent of the cash flows of other assets and liabilities. As such, the Company separately tests individual ethanol plants for recoverability. In addition to the general events and changes in circumstances noted above that indicate that an asset group may not be recoverable, the Company also considers the following events as indicators: the decision to suspend operations at a plant for at least a six month period, or an expected or actual failure to maintain compliance with debt covenants at our ethanol plants. The alternative energy reportable segment includes only income producing asset groups.
Investments and Deposits
Restricted investments, which are principally money market mutual funds and cash deposits, are stated at cost plus accrued interest, which approximates market. Restricted investments at October 31, 2012 and January 31, 2012 are required by two states to cover possible future claims under extended service policies over the remaining lives of the service policy contracts. In accordance with ASC 320, “ Investments-Debt and Equity Securities ” the Company has classified these investments as available for sale.
The method of accounting applied to long-term investments, whether consolidated, equity or cost, involves an evaluation of the significant terms of each investment that explicitly grant or suggest evidence of control or influence over the operations of the investee and also includes the identification of any variable interests in which the Company is the primary beneficiary. The Company consolidates the results of two majority owned subsidiaries, One Earth and NuGen. The results of One Earth are included on a delayed basis of one month. The Company accounts for investments in limited liability companies in which it may have a less than 20% ownership interest, using the equity method of accounting when the factors discussed in ASC 323 “ Investments-Equity Method and Joint Ventures ” are met. The excess of the carrying value over the underlying equity in the net assets of equity method investees is allocated to specific assets and liabilities. Any unallocated excess is treated as goodwill and is recorded as a component of
11
the carrying value of the equity method investee. Investments in businesses that the Company does not control but for which it has the ability to exercise significant influence over operating and financial matters are accounted for using the equity method. Investments in which the Company does not have the ability to exercise significant influence over operating and financial matters are accounted for using the cost method. The Company accounts for its investments in Big River Resources, LLC (“Big River”) and Patriot Holdings, LLC (“Patriot”) using the equity method of accounting and includes the results of these entities on a delayed basis of one month.
The Company periodically evaluates its investments for impairment due to declines in market value considered to be other than temporary. Such impairment evaluations include, in addition to persistent, declining market prices, general economic and company-specific evaluations. If the Company determines that a decline in market value is other than temporary, then a charge to earnings is recorded in the Consolidated Condensed Statements of Operations and a new cost basis in the investment is established.
Accounting Changes and Recently Issued Accounting Standards
Effective February 1, 2012, the Company was required to adopt the third phase of amended guidance in ASC 820 “ Fair Value Measurements and Disclosures ”. The amendment established common fair value measurement and disclosure requirements by improving comparability of fair value measurements presented and disclosed in financial statements prepared in accordance with generally accepted accounting principles in the United States of America (“GAAP”) and those prepared in conformity with International Financial Reporting Standards. The amended guidance clarified the application of existing requirements and requires additional disclosure for Level 3 measurements regarding the sensitivity of fair value to changes in unobservable inputs and any interrelationships between those inputs. The adoption of this amended guidance did expand disclosure related to fair value but, otherwise, did not impact the Company’s consolidated condensed financial statements.
Effective February 1, 2012, the Company was required to adopt the amended guidance in ASC 220 “ Comprehensive Income ”. This amendment increased the prominence of other comprehensive income in the financial statement by eliminating the option to present other comprehensive income in the statement of stockholders’ equity, and rather requiring comprehensive income to be reported in either a single continuous statement or in two separate but consecutive statements reporting net income and other comprehensive income. The adoption of this amended guidance did not impact the Company’s consolidated condensed financial statements.
Note 3.
Leases
At October 31, 2012, the Company has lease agreements, as landlord, for all or portions of six owned former retail stores and one owned former distribution center. All of the leases are
12
accounted for as operating leases. The following table is a summary of future minimum rentals on such leases (amounts in thousands):
|
|
|
|
|
|
|
Years Ended January 31, |
|
Minimum
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Remainder of 2013 |
|
$ |
382 |
|
|
2014 |
|
|
1,468 |
|
|
2015 |
|
|
1,070 |
|
|
2016 |
|
|
511 |
|
|
2017 |
|
|
443 |
|
|
Thereafter |
|
|
1,430 |
|
|
|
|
|
|
|
|
Total |
|
$ |
5,304 |
|
|
|
|
|
|
|
Note 4.
Fair
Value
The Company applies ASC 820, Fair Value Measurements and Disclosures , (“ASC 820”) which provides a framework for measuring fair value under GAAP. This accounting standard defines fair value as the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date.
The Company determines the fair market values of its financial instruments based on the fair value hierarchy established by ASC 820. ASC 820 requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. The standard describes three levels of inputs that may be used to measure fair values which are provided below. The Company carries cash equivalents, investment in cooperative, restricted investments and derivative liabilities at fair value.
Level 1 – Quoted prices in active markets for identical assets or liabilities. Level 1 assets and liabilities include debt and equity securities and derivative contracts that are traded in an active exchange market, as well as certain U.S. Treasury securities that are highly liquid and are actively traded in over-the-counter markets.
Level 2 – Observable inputs other than Level 1 prices such as quoted prices for similar assets or liabilities; quoted prices in markets that are not active; or other inputs that are observable or can be corroborated by observable market data for substantially the full term of the assets or liabilities. Level 2 assets and liabilities include derivative contracts whose value is determined using a pricing model with inputs that are observable in the market or can be derived principally or corroborated by observable market data.
Level 3 – Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. Level 3 assets and liabilities include financial instruments whose value is determined using pricing models, discounted cash flow methods, or similar techniques, as well as instruments for which the determination of fair value requires significant management judgment or estimation. Unobservable inputs shall be
13
developed based on the best information available, which may include the Company’s own data.
The fair values of interest rate swaps are determined by using quantitative models that discount future cash flows using the LIBOR forward interest rate curve. Estimation risk is greater for derivative asset and liability positions that are either option-based or have longer maturity dates where observable market inputs are less readily available or are unobservable, in which case interest rate, price or index scenarios are extrapolated in order to determine the fair value. The fair values of derivative assets and liabilities include adjustments for market liquidity, counterparty credit quality, the Company’s own credit standing and other specific factors, where appropriate.
The fair values of property and equipment, as applicable, are determined by using various models that discount future expected cash flows. Estimation risk is greater for vacant properties as the probability of expected cash flows from the use of vacant properties is difficult to predict.
To ensure the prudent application of estimates and management judgment in determining the fair values of derivative assets and liabilities and property and equipment, various processes and controls have been adopted, which include: model validation that requires a review and approval for pricing, financial statement fair value determination and risk quantification; periodic review and substantiation of profit and loss reporting for all derivative instruments and property and equipment items.
Financial assets and liabilities measured at fair value on a recurring basis at October 31, 2012 are summarized below (amounts in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Level 1 |
|
Level 2 |
|
Level 3 |
|
Fair Value |
|
||||
|
|
|
|
|
|
|
|
|
|
|
||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash equivalents |
|
$ |
2 |
|
$ |
— |
|
$ |
— |
|
$ |
2 |
|
|
Money market mutual fund (1) |
|
|
300 |
|
|
— |
|
|
— |
|
|
300 |
|
|
Investment in cooperative (1) |
|
|
— |
|
|
— |
|
|
219 |
|
|
219 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total assets |
|
$ |
302 |
|
$ |
— |
|
$ |
219 |
|
$ |
521 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest rate swap derivative liabilities |
|
$ |
— |
|
$ |
3,226 |
|
$ |
— |
|
$ |
3,226 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Financial assets and liabilities measured at fair value on a recurring basis at January 31, 2012 are summarized below (amounts in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Level 1 |
|
Level 2 |
|
Level 3 |
|
Fair Value |
|
||||
|
|
|
|
|
|
|
|
|
|
|
||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash equivalents |
|
$ |
2 |
|
$ |
— |
|
$ |
— |
|
$ |
2 |
|
|
Money market mutual fund (1) |
|
|
620 |
|
|
— |
|
|
— |
|
|
620 |
|
|
Investment in cooperative (1) |
|
|
— |
|
|
— |
|
|
219 |
|
|
219 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total assets |
|
$ |
622 |
|
$ |
— |
|
$ |
219 |
|
$ |
841 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest rate swap derivative liabilities |
|
$ |
— |
|
$ |
4,235 |
|
$ |
— |
|
$ |
4,235 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
14
(1) The money market mutual fund is included in “Restricted investments and deposits” and the investment in cooperative is included in “Other assets” on the accompanying Consolidated Condensed Balance Sheets.
The following table provides a reconciliation of the activity related to assets (investment in cooperative) measured at fair value on a recurring basis using Level 3 inputs (amounts in thousands):
|
|
|
|
|
|
|
Balance, January 31, 2012 |
|
$ |
219 |
|
|
Current period activity |
|
|
— |
|
|
|
|
|
|
|
|
Balance, October 31, 2012 |
|
$ |
219 |
|
|
|
|
|
|
|
The Company determined the fair value of the investment in cooperative by using a discounted cash flow analysis on the expected cash flows. Inputs used in the analysis include the face value of the allocated equity amount, the projected term for repayment based upon a historical trend, and a risk adjusted discount rate based on the expected compensation participants would demand because of the uncertainty of the future cash flows. The inherent risk and uncertainty associated with unobservable inputs could have a significant effect on the actual fair value of the investment.
Assets measured at fair value on a non-recurring basis for the first nine months of fiscal year 2012 are summarized below (amounts in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Level 1 |
|
Level 2 |
|
Level 3 |
|
Total
|
|
||||
|
|
|
|
|
|
|
|
|
|
|
||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property and equipment, net |
|
$ |
— |
|
$ |
— |
|
$ |
1,364 |
|
$ |
307 |
|
Assets measured at fair value on a non-recurring basis over various dates through January 31, 2012 are summarized below (amounts in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Level 1 |
|
Level 2 |
|
Level 3 |
|
Total
|
|
||||
|
|
|
|
|
|
|
|
|
|
|
||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property and equipment, net |
|
$ |
— |
|
$ |
— |
|
$ |
8,803 |
|
$ |
1,227 |
|
(1) Total losses include impairment charges and loss on disposal.
The fair value of the Company’s debt is approximately $108.6 million and $123.7 million at October 31, 2012 and January 31, 2012, respectively. The fair value was estimated with Level 2 inputs using a discounted cash flow analysis and the Company’s estimate of market rates of interest for similar loan agreements with companies that have a similar credit risk.
Note 5.
Property and
Equipment
The components of property and equipment at October 31, 2012 and January 31, 2012 are
15
as follows (amounts in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
October
31,
|
|
January
31,
|
|
||
|
|
|
|
|
|
|
||
|
|
|||||||
|
Land and improvements |
|
$ |
24,253 |
|
$ |
25,094 |
|
|
Buildings and improvements |
|
|
38,752 |
|
|
40,710 |
|
|
Machinery, equipment and fixtures |
|
|
221,504 |
|
|
212,797 |
|
|
Leasehold improvements |
|
|
— |
|
|
366 |
|
|
Construction in progress |
|
|
104 |
|
|
7,194 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
284,613 |
|
|
286,161 |
|
|
Less: accumulated depreciation |
|
|
(56,802 |
) |
|
(46,077 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
$ |
227,811 |
|
$ |
240,084 |
|
|
|
|
|
|
|
|
|
|
Note 6.
Other Assets
The components of other assets at October 31, 2012 and January 31, 2012 are as follows (amounts in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
October
31,
|
|
January
31,
|
|
||
|
|
|
|
|
|
|
||
|
|
|||||||
|
Deferred financing costs, net |
|
$ |
903 |
|
$ |
1,306 |
|
|
Prepaid commissions |
|
|
262 |
|
|
729 |
|
|
Deposits |
|
|
2,514 |
|
|
2,564 |
|
|
Real estate taxes refundable |
|
|
1,969 |
|
|
1,969 |
|
|
Other |
|
|
1,145 |
|
|
1,316 |
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
6,793 |
|
$ |
7,884 |
|
|
|
|
|
|
|
|
|
|
Note 7.
Long Term
Debt and Interest Rate Swaps
One Earth Energy
Subsidiary Level Debt
In September 2007, One Earth entered into a $111,000,000 financing agreement consisting of a construction loan agreement for $100,000,000 together with a $10,000,000 annually renewable revolving loan and a $1,000,000 letter of credit with First National Bank of Omaha (“the Bank”). The construction loan was converted into a term loan on July 31, 2009. The term loan bears interest at variable interest rates ranging from LIBOR plus 280 basis points to LIBOR plus 300 basis points (3.3% -3.5% at October 31, 2012). Beginning with the first quarterly payment on October 8, 2009, payments are due in 19 quarterly payments of principal plus accrued interest with the principal portion calculated based on a 120 month amortization schedule. One final installment will be required on the maturity date (July 31, 2014) for the remaining unpaid principal balance with accrued interest. Principal payments equal to 20% of annual excess cash flows are also due. Such payments cannot exceed $6 million in a year.
Borrowings are secured by all of the assets of One Earth. This debt is recourse only to One Earth and not to REX American Resources Corporation or any of its other subsidiaries. As
16
of October 31, 2012, approximately $58.2 million was outstanding on the term loan. One Earth is also subject to certain financial covenants under the loan agreement, including debt service coverage ratio requirements and working capital requirements. One Earth was in compliance with these covenants, as applicable, at October 31, 2012. One Earth has paid approximately $1.4 million in financing costs. These costs are recorded as deferred financing costs and are amortized ratably over the term of the loan.
The Company’s proportionate share of restricted net assets related to One Earth was approximately $78.2 million and $70.2 million at October 31, 2012 and January 31, 2012, respectively. Restricted net assets may not be paid in the form of dividends or advances to the parent company or other members of One Earth per the terms of the loan agreement with the Bank.
As of the end of its third quarter, One Earth has no outstanding borrowings on the $10,000,000 revolving loan, which expires on May 29, 2013, nor any outstanding letters of credit.
One Earth entered into two forward interest rate swaps in the notional amounts of $50.0 million and $25.0 million with the Bank. The swap settlements commenced as of July 31, 2009; the $50.0 million swap terminates on July 8, 2014 and the $25.0 million swap terminated on July 31, 2011. The $50.0 million swap fixed a portion of the variable interest rate of the term loan subsequent to the plant completion date at 7.9% while the $25.0 million swap fixed the rate at 5.49%. At October 31, 2012 and January 31, 2012, the Company recorded a liability of approximately $3.2 million and $4.2 million, respectively, related to the fair value of the remaining swap. The change in fair value is recorded in the Consolidated Condensed Statements of Operations.
NuGen Energy Subsidiary Level Debt
In November 2011, NuGen entered into a $65,000,000 financing agreement consisting of a term loan agreement for $55,000,000 and a $10,000,000 annually renewable revolving loan with First National Bank of Omaha (“the Bank”). The term loan bears interest at variable interest rate of LIBOR plus 325 basis points, subject to a 4% floor (4% at October 31, 2012). Beginning with the first quarterly payment on February 1, 2012, payments are due in 19 quarterly payments of principal plus accrued interest with the principal portion calculated based on a 120 month amortization schedule. One final installment will be required on the maturity date (October 31, 2016) for the remaining unpaid principal balance with accrued interest. Principal payments equal to 40% of annual excess cash flows are also due. Such payments cannot exceed $5 million in a year.
Borrowings are secured by all of the assets of NuGen. This debt is recourse only to NuGen and not to REX American Resources Corporation or any of its other subsidiaries. As of October 31, 2012, approximately $49.5 million was outstanding on the term loan. NuGen is also subject to certain financial covenants under the loan agreement, including debt service coverage ratio requirements (beginning with the quarter and fiscal year ending January 31, 2013) and working capital requirements. NuGen was in compliance with these covenants, as applicable, at
17
October 31, 2012. NuGen has paid approximately $0.6 million in financing costs. These costs are recorded as deferred financing costs and are amortized ratably over the term of the loan.
The Company’s proportionate share of restricted net assets related to NuGen was approximately $53.3 million and approximately $50.4 million at October 31, 2012 and January 31, 2012, respectively. Restricted net assets may not be paid in the form of dividends or advances to the parent company or other members of NuGen per the terms of the loan agreement with the Bank.
NuGen has no outstanding borrowings on the $10,000,000 revolving loan as of October 31, 2012 which expires on May 31, 2013.
Note 8.
Financial Instruments
The Company uses interest rate swaps to manage its interest rate exposure at One Earth by fixing the interest rate on a portion of the entity’s variable rate debt. The Company does not engage in trading activities involving derivative contracts for which a lack of marketplace quotations would necessitate the use of fair value estimation techniques. The notional amounts and fair values of derivatives, all of which are not designated as cash flow hedges at October 31, 2012 are summarized in the table below (amounts in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
Notional
|
|
Fair
Value
|
|
||
|
|
|
|
|
|
|
||
|
|
|
|
|
|
|
|
|
|
Interest rate swap |
|
$ |
38,841 |
|
$ |
3,226 |
|
As the interest rate swaps are not designated as cash flow hedges, the unrealized gain and loss on the derivatives is reported in current earnings. The Company reported losses of $140,000 and $501,000 in the third quarter of fiscal years 2012 and 2011, respectively. The Company reported losses of $366,000 and $1,190,000 in the first nine months of fiscal years 2012 and 2011, respectively.
Note 9
. Stock Option Plans
The Company has stock-based compensation plans under which stock options have been granted to directors, officers and key employees at the market price on the date of the grant. No options have been granted since fiscal year 2004.
The total intrinsic value of options exercised during the nine months ended October 31, 2012 and 2011 was approximately $1.8 million and $3.1 million, respectively, resulting in tax deductions to realize benefits of approximately $0.3 million and $0.6 million, respectively. The
18
following table summarizes options granted, exercised and canceled or expired during the nine months ended October 31, 2012:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Shares |
|
Weighted
|
|
Weighted Average
|
|
Aggregate
|
|
||||
|
|
|
|
|
|
|
|
|
|
|
||||
|
Outstanding at January 31, 2012 |
|
|
268,723 |
|
$ |
13.15 |
|
|
|
|
|
|
|
|
Exercised |
|
|
(99,968 |
) |
$ |
14.30 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding and exercisable at October 31, 2012 |
|
|
168,755 |
|
$ |
12.46 |
|
|
1.3 |
|
$ |
869 |
|
During the first nine months of fiscal year 2012, certain officers and directors of the Company tendered 32,935 shares of the Company’s common stock as payment of the exercise price of stock options exercised pursuant to the Company’s Stock-for-Stock and Cashless Option Exercise Rules and Procedures, adopted on June 4, 2001. The purchase price was $32.53 per share.
At October 31, 2012, there was no unrecognized compensation cost related to nonvested stock options.
Note 10.
Income Per
Share from Continuing Operations Attributable to REX Common Shareholders
The following table reconciles the computation of basic and diluted net income per share from continuing operations for the periods presented (in thousands, except per share amounts):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Three Months Ended
|
|
||||||||||||||
|
|
|
|
|
|
|
||||||||||||||
|
|
|
Income |
|
Shares |
|
Per
|
|
Income |
|
Shares |
|
Per
|
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
|
Basic income per share from continuing operations attributable to REX common shareholders |
|
$ |
272 |
|
|
8,226 |
|
$ |
0.03 |
|
$ |
6,029 |
|
|
9,205 |
|
$ |
0.65 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effect of stock options |
|
|
— |
|
|
32 |
|
|
|
|
|
— |
|
|
34 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted income per share from continuing operations attributable to REX common shareholders |
|
$ |
272 |
|
|
8,258 |
|
$ |
0.03 |
|
$ |
6,029 |
|
|
9,239 |
|
$ |
0.65 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
19
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended
|
|
Nine Months Ended
|
|
||||||||||||||
|
|
|
|
|
|
|
||||||||||||||
|
|
|
Income |
|
Shares |
|
Per
|
|
Income |
|
Shares |
|
Per
|
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
|
Basic income per share from continuing operations attributable to REX common shareholders |
|
$ |
1,707 |
|
|
8,311 |
|
$ |
0.21 |
|
$ |
12,200 |
|
|
9,385 |
|
$ |
1.30 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effect of stock options |
|
|
— |
|
|
50 |
|
|
|
|
|
— |
|
|
68 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted income per share from continuing operations attributable to REX common shareholders |
|
$ |
1,707 |
|
|
8,361 |
|
$ |
0.21 |
|
$ |
12,200 |
|
|
9,453 |
|
$ |
1.29 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the three and nine months ended October 31, 2012 and 2011, there were no shares subject to outstanding options that were not included in the common equivalent shares outstanding calculation as the effect from these shares was antidilutive.
Note 11.
Investments
and Restricted Deposits
The Company has approximately $203,000 and $743,000 at October 31, 2012 and January 31, 2012, respectively, on deposit with the Florida Department of Financial Services to secure its obligation to fulfill future obligations related to extended warranty contracts sold in the state of Florida. As such, this deposit is restricted from use for general corporate purposes.
In addition to the deposit with the Florida Department of Financial Services, the Company has $300,000 at October 31, 2012 and $620,000 at January 31, 2012 invested in a money market mutual fund to satisfy Florida Department of Financial Services regulations. As such, this investment is restricted from use for general corporate purposes.
The following table summarizes equity method investments at October 31, 2012 and January 31, 2012 (amounts in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Entity |
|
Ownership
|
|
Carrying Amount
|
|
Carrying Amount
|
|
||||
|
|
|
|
|
|
|
|
|
||||
|
|
|
|
|
|
|
|
|
||||
|
Big River |
|
|
10 |
% |
$ |
32,530 |
|
$ |
34,370 |
|
|
|
Patriot |
|
|
27 |
% |
|
28,542 |
|
|
27,309 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Equity Method Investments |
|
|
|
|
$ |
61,072 |
|
$ |
61,679 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
20
The following table summarizes (loss) or income recognized from equity method investments for the periods presented (amounts in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
|
||||
|
|
|
|
|
|
|
|
|
|
|
||||
|
|
|||||||||||||
|
Big River |
|
$ |
(496 |
) |
$ |
1,552 |
|
$ |
165 |
|
$ |
4,406 |
|
|
Patriot |
|
|
2,038 |
|
|
1,985 |
|
|
1,338 |
|
|
3,358 |
|
|
NuGen |
|
|
— |
|
|
2,747 |
|
|
— |
|
|
8,063 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
1,542 |
|
$ |
6,284 |
|
$ |
1,503 |
|
$ |
15,827 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effective July 1, 2010, the Company purchased a 48% equity interest in NuGen which operates an ethanol producing facility in Marion, South Dakota with an annual nameplate capacity of 100 million gallons. The Company accounted for this investment using the equity method of accounting. On November 1, 2011, the Company acquired an additional 50% equity interest in NuGen. Following the purchase, the Company owned all of the outstanding Class A membership interest units in NuGen, representing a 100% voting interest and a 98% equity interest in NuGen. Effective November 1, 2011, the Company ceased using the equity method of accounting and began consolidating the results of NuGen. Prior to consolidation, the Company recorded the results of NuGen on a one month lag. During fiscal year 2011, NuGen adopted the same fiscal year as the Company. As a result, the Company no longer records the results of NuGen on a one month lag. NuGen repurchased shares from noncontrolling interests holders during fiscal year 2012. This increased the Company’s equity interest in NuGen to 99%.
Undistributed earnings of Big River and Patriot totaled approximately $22.3 million and $22.8 million at October 31, 2012 and January 31, 2012, respectively. During the first nine months of fiscal years 2012 and 2011, the Company received dividends from equity method investees of approximately $2.0 million and $2.3 million, respectively.
Summarized financial information for each of the Company’s equity method investees except for NuGen is presented in the following table for the three and nine months ended
21
September 30, 2012 and 2011. The summarized financial information for NuGen is presented for the three and nine months ended October 31, 2011 (amounts in thousands):
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Big River |
|
Patriot |
|
||
|
|
|
|
|
|
|
||
|
|
|
|
|
|
|
||
|
Net sales and revenue |
|
$ |
306,808 |
|
$ |
100,231 |
|
|
Gross (loss) profit |
|
$ |
(14,116 |
) |
$ |
8,897 |
|
|
(Loss) income from continuing operations |
|
$ |
(5,109 |
) |
$ |
7,678 |
|
|
Net (loss) income |
|
$ |
(5,109 |
) |
$ |
7,678 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Big River |
|
Patriot |
|
NuGen |
|
|||
|
|
|
|
|
|
|
|
|
|||
|
|
|
|
|
|
|
|
|
|||
|
Net sales and revenue |
|
$ |
314,200 |
|
$ |
94,580 |
|
$ |
87,620 |
|
|
Gross profit |
|
$ |
32,849 |
|
$ |
10,241 |
|
$ |
7,433 |
|
|
Income from continuing operations |
|
$ |
15,959 |
|
$ |
8,513 |
|
$ |
5,831 |
|
|
Net income |
|
$ |
15,959 |
|
$ |
8,513 |
|
$ |
5,831 |
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended
|
|
Big River |
|
Patriot |
|
||
|
|
|
|
|
|
|
||
|
|
|
|
|
|
|
||
|
Net sales and revenue |
|
$ |
856,659 |
|
$ |
271,620 |
|
|
Gross profit |
|
$ |
8,399 |
|
$ |
10,105 |
|
|
Income from continuing operations |
|
$ |
1,677 |
|
$ |
5,032 |
|
|
Net income |
|
$ |
1,677 |
|
$ |
5,032 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended
|
|
Big River |
|
Patriot |
|
NuGen |
|
|||
|
|
|
|
|
|
|
|
|
|||
|
|
|
|
|
|
|
|
|
|||
|
Net sales and revenue |
|
$ |
845,926 |
|
$ |
284,546 |
|
$ |
255,671 |
|
|
Gross profit |
|
$ |
64,349 |
|
$ |
19,775 |
|
$ |
22,425 |
|
|
Income from continuing operations |
|
$ |
45,319 |
|
$ |
14,401 |
|
$ |
16,822 |
|
|
Net income |
|
$ |
45,319 |
|
$ |
14,401 |
|
$ |
16,822 |
|
Patriot and Big River have debt agreements that limit and restrict amounts the companies can pay in the form of dividends or advances to owners. The restricted net assets of Patriot and Big River combined at October 31, 2012 and January 31, 2012 are approximately $369.9 million and $326.2 million, respectively. The Company’s proportionate share of restricted net assets of Patriot and Big River combined at October 31, 2012 and January 31, 2012 are approximately $54.0 million and $44.2 million, respectively.
22
The Company previously held an ownership interest in Levelland Hockley County Ethanol, LLC (“Levelland Hockley”) which owned an ethanol plant in Levelland, Texas. On April 27, 2011, Levelland Hockley voluntarily filed for protection under Chapter 11 of the United States Bankruptcy Code in the United States Bankruptcy Court, Northern District of Texas. In connection with the bankruptcy proceedings, the plant was sold on May 14, 2012 and on August 1, 2012, the bankruptcy case was converted to a Chapter 7 proceeding. As a result, we have no remaining ownership or financial interest in Levelland Hockley and will classify the results of Levelland Hockley as discontinued operations. No periods presented in the Consolidated Condensed Financial Statements were affected by this classification. However, future periodic reports filed with the Securities and Exchange Commission will be affected as years prior to fiscal year 2011 are required to be included in such filings.
Note 12
. Income
Taxes
The effective tax rate on consolidated pre-tax income from continuing operations was 15.1% for the three months ended October 31, 2012, and 34.0% for the three months ended October 31, 2011. The effective tax rate on consolidated pre-tax income from continuing operations was 27.4% for the nine months ended October 31, 2012, and 36.0% for the nine months ended October 31, 2011. The fluctuations in the effective tax rate primarily relate to the presentation of noncontrolling interests in the income of consolidated subsidiaries as noncontrolling interests are presented in the Consolidated Condensed Statements of Operations after the income tax provision or benefit.
The Company files a U.S. federal income tax return and income tax returns in various states. In general, the Company is no longer subject to U.S. federal, state or local income tax examinations by tax authorities for years ended January 31, 2008 and prior. A reconciliation of the beginning and ending amount of unrecognized tax benefits, including interest and penalties, is as follows (amounts in thousands):
|
|
|
|
|
|
|
Unrecognized tax benefits, January 31, 2012 |
|
$ |
2,484 |
|
|
Changes for prior years’ tax positions |
|
|
47 |
|
|
Changes for current year tax positions |
|
|
— |
|
|
|
|
|
|
|
|
Unrecognized tax benefits, October 31, 2012 |
|
$ |
2,531 |
|
|
|
|
|
|
|
Note 13.
Discontinued
Operations
During fiscal year 2009, the Company completed the exit of its retail business. Accordingly, all operations of the Company’s former retail segment and certain sold properties have been classified as discontinued operations for all periods presented. Once real estate property has been sold, and no continuing involvement is expected, the Company classifies the results of the operations as discontinued operations. The results of operations were previously reported in the Company’s retail or real estate segment, depending on when the store ceased operations. Below is a table reflecting certain items of the Consolidated Condensed Statements
23
of Operations that were reclassified as discontinued operations for the periods indicated (amounts in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
|
||||
|
|
|
|
|
|
|
|
|
|
|
||||
|
|
|
(In Thousands) |
|
||||||||||
|
Net sales and revenue |
|
$ |
434 |
|
$ |
921 |
|
$ |
1,549 |
|
$ |
3,411 |
|
|
Cost of sales |
|
|
52 |
|
|
194 |
|
|
361 |
|
|
741 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes |
|
|
179 |
|
|
298 |
|
|
601 |
|
|
1,401 |
|
|
Provision for income taxes |
|
|
(72 |
) |
|
(112 |
) |
|
(240 |
) |
|
(545 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from discontinued operations, net of tax |
|
$ |
107 |
|
$ |
186 |
|
$ |
361 |
|
$ |
856 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gain on disposal |
|
$ |
50 |
|
$ |
429 |
|
$ |
133 |
|
$ |
695 |
|
|
Provision for income taxes |
|
|
(20 |
) |
|
(162 |
) |
|
(53 |
) |
|
(270 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gain on disposal of discontinued operations, net of tax |
|
$ |
30 |
|
$ |
267 |
|
$ |
80 |
|
$ |
425 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Note 14.
Commitments
and Contingencies
The Company is involved in various legal actions arising in the normal course of business. After taking into consideration legal counsels’ evaluations of such actions, management is of the opinion that their outcome will not have a material effect on the Company’s consolidated condensed financial statements.
One Earth and NuGen have combined forward purchase contracts for approximately 18.9 million bushels of corn, the principal raw material for their ethanol plants. They expect to take delivery of the grain through March 2013.
One Earth and NuGen have combined sales commitments for approximately 45.1 million gallons of ethanol, approximately 49,000 tons of distillers grains and approximately 4.7 million pounds of non-food grade corn oil. They expect to deliver the ethanol, distillers grains and non-food grade corn oil through March 2013.
Note 15.
Segment
Reporting
The Company has two segments: alternative energy and real estate. The Company evaluates the performance of each reportable segment based on segment profit. Segment profit excludes income taxes, indirect interest expense, discontinued operations, indirect interest income and certain other items that are included in net income determined in accordance with GAAP.
24
Segment profit includes realized and unrealized gains on derivative financial instruments. The following table summarizes segment and other results and assets (amounts in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
|
||||
|
|
|
|
|
|
|
|
|
|
|
||||
|
Net sales and revenue: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Alternative energy |
|
$ |
178,495 |
|
$ |
84,144 |
|
$ |
481,938 |
|
$ |
238,557 |
|
|
Real estate |
|
|
455 |
|
|
380 |
|
|
1,184 |
|
|
926 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total net sales and revenues |
|
$ |
178,950 |
|
$ |
84,524 |
|
$ |
483,122 |
|
$ |
239,483 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Segment gross profit (loss): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Alternative energy |
|
$ |
3,686 |
|
$ |
8,965 |
|
$ |
16,224 |
|
$ |
14,694 |
|
|
Real estate |
|
|
(39 |
) |
|
53 |
|
|
(117 |
) |
|
(1,171 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total gross profit |
|
$ |
3,647 |
|
$ |
9,018 |
|
$ |
16,107 |
|
$ |
13,523 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
|
||||
|
|
|
|
|
|
|
|
|
|
|
||||
|
Segment profit (loss): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Alternative energy |
|
$ |
1,586 |
|
$ |
12,394 |
|
$ |
6,478 |
|
$ |
22,827 |
|
|
Real estate |
|
|
(91 |
) |
|
7 |
|
|
(277 |
) |
|
(1,306 |
) |
|
Corporate expense |
|
|
(603 |
) |
|
(521 |
) |
|
(1,751 |
) |
|
(1,738 |
) |
|
Interest expense |
|
|
(21 |
) |
|
(25 |
) |
|
(65 |
) |
|
(87 |
) |
|
Income from synthetic fuel partnerships |
|
|
— |
|
|
— |
|
|
— |
|
|
2,883 |
|
|
Interest income |
|
|
19 |
|
|
74 |
|
|
68 |
|
|
289 |
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
Income from continuing operations before income taxes and noncontrolling interests |
|
$ |
890 |
|
$ |
11,929 |
|
$ |
4,453 |
|
$ |
22,868 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
October 31, 2012 |
|
January 31, 2012 |
|
||
|
|
|
|
|
|
|
||
|
Assets: |
|
|
|
|
|
|
|
|
Alternative energy |
|
$ |
351,406 |
|
$ |
367,029 |
|
|
Real estate |
|
|
13,945 |
|
|
17,458 |
|
|
Corporate |
|
|
52,762 |
|
|
53,562 |
|
|
|
|
|
|
|
|
|
|
|
Total assets |
|
$ |
418,113 |
|
$ |
438,049 |
|
|
|
|
|
|
|
|
|
|
25
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
|
||||
|
|
|
|
|
|
|
|
|
|
|
||||
|
Sales of products alternative energy segment: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ethanol |
|
|
74 |
% |
|
83 |
% |
|
76 |
% |
|
82 |
% |
|
Distillers grains |
|
|
23 |
% |
|
17 |
% |
|
21 |
% |
|
18 |
% |
|
Other |
|
|
3 |
% |
|
— |
% |
|
3 |
% |
|
— |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
|
100 |
% |
|
100 |
% |
|
100 |
% |
|
100 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Sales of services real estate segment: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease revenue |
|
|
100 |
% |
|
100 |
% |
|
100 |
% |
|
100 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Certain corporate costs and expenses, including information technology, employee benefits and other shared services are allocated to the business segments. The allocations are generally amounts agreed upon by management and are based on a reasonable and systematic approach, which may differ from amounts that would be incurred if such services were purchased separately by the business segment. Corporate assets are primarily cash and deferred income tax benefits.
Cash, except for cash held by One Earth and NuGen, is considered to be fungible and available for both corporate and segment use depending on liquidity requirements. Cash of approximately $20.2 million held by One Earth and NuGen will be used primarily to fund working capital needs for the subsidiaries.
Note 16.
Related-Party
Transactions
During the third quarters of fiscal year 2012 and 2011, One Earth purchased approximately $79.0 million and $63.6 million of corn from the Alliance Grain Elevator, an equity investor in One Earth. Such purchases, inclusive of procurement fees, totaled approximately $199.9 million and approximately $191.0 million for the nine months ended October 31, 2012 and 2011, respectively.
I tem 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
Historically, we were a specialty retailer in the consumer electronics/appliance industry serving small to medium-sized towns and communities. In addition, we have been an investor in various alternative energy entities beginning with synthetic fuel partnerships in 1998 and later ethanol production facilities beginning in 2006.
We completed our exit of the retail business as of July 31, 2009. Going forward, we expect that our only retail related activities will consist of the administration of previously sold extended service plans and the payment of related claims. All activities related to extended service plans are classified as discontinued operations. In addition, we have owned real estate remaining from our former retail store operations. The real estate consists of 18 former retail
26
stores and one distribution center which we include in our real estate segment.
At October 31, 2012, we had equity investments in four ethanol limited liability companies, two of which we have a majority ownership interest in. We may consider making additional investments in the alternative energy segment in future periods. The following table is a summary of ethanol gallons shipped at our plants at October 31, 2012:
|
|
|
|
|
|
|
|
|
|
Entity |
|
Trailing 12
|
|
REX’s
|
|
Current Effective
|
|
|
|
|
|
|
|
|
|
|
|
One Earth Energy, LLC |
|
109.4 M |
|
74 |
% |
81.0 M |
|
|
NuGen Energy, LLC |
|
113.0 M |
|
99 |
% |
111.9 M |
|
|
Patriot Holdings, LLC |
|
117.0 M |
|
27 |
% |
31.6 M |
|
|
Big River Resources W Burlington, LLC |
|
97.8 M |
|
10 |
% |
9.8 M |
|
|
Big River Resources Galva, LLC |
|
102.2 M |
|
10 |
% |
10.2 M |
|
|
Big River United Energy, LLC |
|
107.6 M |
|
5 |
% |
5.4 M |
|
|
Big River Resources Boyceville, LLC (1) |
|
47.2 M |
|
10 |
% |
4.7 M |
|
|
Total |
|
694.2 M |
|
|
|
254.6 M |
|
|
|
|
|
|
|
(1) |
Our current effective annual gallons sold represents ten months of ownership of Big River Resources Boyceville, LLC. |
Our ethanol operations are highly dependent on commodity prices, especially prices for corn, ethanol, distillers grains and natural gas. As a result of price volatility for these commodities, our operating results can fluctuate substantially. The price and availability of corn is subject to significant fluctuations depending upon a number of factors that affect commodity prices in general, including crop conditions, weather, federal policy and foreign trade. Because the market price of ethanol is not always directly related to corn prices, at times ethanol prices may lag movements in corn prices and, in an environment of higher prices, reduce the overall margin structure at the plants. As a result, at times, we may operate our plants at negative or marginally positive operating margins.
We expect our ethanol plants to produce approximately 2.8 gallons of denatured ethanol for each bushel of grain processed in the production cycle. We refer to the difference between the price per gallon of ethanol and the price per bushel of grain (divided by 2.8) as the “crush spread”. Should the crush spread decline, it is possible that our ethanol plants will generate operating results that do not provide adequate cash flows for sustained periods of time. In such cases, production at the ethanol plants may be reduced or stopped altogether in order to minimize variable costs at individual plants. We expect these decisions to be made on an individual plant basis, as there are different market conditions at each of our ethanol plants.
We attempt to manage the risk related to the volatility of grain and ethanol prices by utilizing forward grain purchase and forward ethanol and distillers grains sale contracts. We
27
attempt to match quantities of ethanol and distillers grains sale contracts with an appropriate quantity of grain purchase contracts over a given period of time when we can obtain an adequate gross margin resulting from the crush spread inherent in the contracts we have executed. However, the market for future ethanol sales contracts is not a mature market. Consequently, we generally execute fixed price contracts for no more than three months into the future at any given time. As a result of the relatively short period of time our contracts cover, we generally cannot predict the future movements in the crush spread for more than three months; thus, we are unable to predict the likelihood or amounts of future income or loss from the operations of our ethanol facilities.
Critical Accounting Policies and Estimates
During the three months ended October 31, 2012, we did not change any of our critical accounting policies as disclosed in our 2011 Annual Report on Form 10-K as filed with the Securities and Exchange Commission on April 9, 2012. All other accounting policies used in preparing our interim fiscal year 2012 Consolidated Condensed Financial Statements are the same as those described in our Form 10-K.
Fiscal Year
All references in this report to a particular fiscal year are to REX’s fiscal year ended January 31. For example, “fiscal year 2012” means the period February 1, 2012 to January 31, 2013.
Results of Operations
For a detailed analysis of period to period changes, see the segment discussion that follows this section as this is how management views and monitors our business.
Comparison of Three Months and Nine Months Ended October 31, 2012 and 2011
Net sales and revenue in the quarter ended October 31, 2012 were approximately $179.0 million compared to approximately $84.5 million in the prior year’s third quarter, representing an increase of approximately $94.5 million. Net sales and revenue do not include sales from real estate operations classified as discontinued operations. The increase was primarily caused by higher sales in our alternative energy segment of approximately $94.4 million. Net sales and revenue from our real estate segment were approximately $0.5 million in the third quarter of fiscal year 2012 and approximately $0.4 million in the third quarter of fiscal year 2011.
Net sales and revenue for the first nine months of fiscal year 2012 were approximately $483.1 million compared to approximately $239.5 million for the first nine months of fiscal year 2011. This represents an increase of approximately $243.6 million. The increase was primarily caused by higher sales in our alternative energy segment of approximately $243.4 million.
28
Net sales and revenue from our real estate segment were approximately $1.2 million in the first nine months of fiscal year 2012 and approximately $0.9 million in the first nine months of fiscal year 2011.
The following table reflects the approximate percent of net sales for each major product and service group for the following periods:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
||||||||
|
Product Category |
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
|
||||
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
Ethanol |
|
|
74 |
% |
|
82 |
% |
|
76 |
% |
|
81 |
% |
|
|
Distillers grains |
|
|
23 |
|
|
17 |
|
|
21 |
|
|
18 |
|
|
|
Other |
|
|
3 |
|
|
1 |
|
|
3 |
|
|
1 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
|
100 |
% |
|
100 |
% |
|
100 |
% |
|
100 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit for the third quarter of fiscal year 2012 was approximately $3.6 million (2.0% of net sales and revenue) which was approximately $5.4 million lower compared to approximately $9.0 million of gross profit (10.7% of net sales and revenue) for the third quarter of fiscal year 2011. Gross profit for the third quarter of fiscal year 2012 decreased by approximately $5.3 million compared to the prior year from our alternative energy segment. Gross loss for the third quarter of fiscal year 2012 was approximately $39,000 compared to gross profit of approximately $53,000 for the third quarter of fiscal year 2011 from our real estate segment.
Gross profit for the first nine months of fiscal year 2012 was approximately $16.1 million (3.3% of net sales and revenue) which was approximately $2.6 million higher compared to approximately $13.5 million (5.6% of net sales and revenue) for the first nine months of fiscal year 2011. Gross profit for the nine months ended October 31, 2012 increased by approximately $1.5 million compared to the prior year as a result of operations in the alternative energy segment. Gross loss for the first nine months of fiscal year 2012 decreased by approximately $1.1 million compared to the prior year from our real estate segment.
Selling, general and administrative expenses for the third quarter of fiscal year 2012 were approximately $3.0 million (1.7% of net sales and revenue), an increase of approximately $0.7 million from approximately $2.3 million (2.8% of net sales and revenue) for the third quarter of fiscal year 2011. The increase was primarily caused by higher expenses in our alternative energy segment of approximately $0.6 million. Selling, general and administrative expenses were approximately $9.2 million (1.9% of net sales and revenue) for the first nine months of fiscal year 2012 representing an increase of approximately $2.6 million from approximately $6.6 million (2.8% of net sales and revenue) for the first nine months of fiscal year 2011. For the first nine months of fiscal year 2012, these expenses increased approximately $2.5 million compared to the prior year in the alternative energy segment.
During the third quarter of fiscal years 2012 and 2011, we recognized income of approximately $1.5 million and $6.3 million, respectively, from our equity investments in Big River, Patriot and NuGen. During the first nine months of fiscal years 2012 and 2011, we
29
recognized income of approximately $1.5 million and $15.8 million, respectively, from these investments. Effective November 1, 2011, we acquired an additional 50% equity interest in NuGen, which operates an ethanol producing facility in Marion, South Dakota which shipped approximately 113 million gallons of ethanol in the trailing 12 months ended October 31, 2012. As of November 1, 2011, we ceased using the equity method of accounting for NuGen and began consolidating their results prospectively. We acquired our initial 48% ownership interest in NuGen on July 1, 2010. We currently have a 99% equity interest in NuGen. Big River has an effective ownership of ethanol gallons shipped in the trailing twelve months ended October 31, 2012 of approximately 301 million gallons. Patriot has one plant which shipped approximately 117 million gallons of ethanol in the trailing 12 months ended October 31, 2012.
Due to the inherent volatility of the crush spread, we cannot predict the likelihood of future operating results from Big River and Patriot being similar to historical results.
During the first nine months of fiscal year 2011, we recognized income of approximately $2.9 million from the sale of a synthetic fuel partnership we sold in fiscal year 2005. This income represents one final payment for synthetic fuel production occurring during fiscal year 2008. We will not recognize any additional income from this investment.
Interest income was approximately $42,000 and $92,000 for the third quarter of fiscal years 2012 and 2011, respectively. Interest income was approximately $132,000 and $364,000 for the first nine months of fiscal years 2012 and 2011, respectively. The decline is primarily related to lower levels of excess cash invested and lower yields earned during fiscal year 2012 compared to the prior year.
Interest expense was approximately $1.2 million for the third quarter of fiscal year 2012 compared to approximately $0.6 million for the third quarter of fiscal year 2011, an increase of approximately $0.6 million. Interest expense was approximately $3.7 million for the first nine months of fiscal year 2012 compared to approximately $1.9 million for the first nine months of fiscal year 2011, an increase of approximately $1.8 million. These increases were primarily attributable to the alternative energy segment as we consolidated NuGen in fiscal year 2012 which had approximately $0.6 million of interest expense in the third quarter of fiscal year 2012 and approximately $1.8 million of interest expense for the first nine months of fiscal year 2012.
We recognized losses of approximately $0.1 million and $0.5 million during the third quarter of fiscal years 2012 and 2011, respectively, related to a forward interest rate swap that One Earth entered into during fiscal year 2007. We recognized losses related to the swap of approximately $0.4 million during the first nine months of fiscal year 2012 compared to approximately $1.2 million during the first nine months of fiscal year 2011. In general, declining interest rates have a negative effect on our interest rate swaps and vice versa, as our swaps fixed the interest rate of variable rate debt. Should interest rates decline, we would expect to experience losses on the interest rate swaps. We would expect to incur gains on the interest rate swaps should interest rates increase. We cannot predict the future movements in interest rates; thus, we are unable to predict the likelihood or amounts of future gains or losses related to interest rate swaps.
30
As a result of the foregoing, income from continuing operations before income taxes was approximately $0.9 million for the third quarter of fiscal year 2012 versus approximately $11.9 million for the third quarter of fiscal year 2011. Income from continuing operations before income taxes was approximately $4.5 million for the first nine months of fiscal year 2012 versus approximately $22.9 million for the first nine months of fiscal year 2011.
Our effective tax rate was 15.1% and 34.0% for the third quarter of fiscal years 2012 and 2011, respectively. Our effective tax rate for the first nine months of fiscal year 2012 was 27.4% compared to 36.0% for the first nine months of fiscal year 2011. The fluctuations in the effective tax rate primarily relate to the presentation of noncontrolling interests in the income of consolidated subsidiaries as noncontrolling interests are presented in the Consolidated Condensed Statements of Operations after the income tax provision or benefit. The noncontrolling interests in the income of One Earth and NuGen was a higher proportion of consolidated pre-tax income in fiscal year 2012 compared to fiscal year 2011.
As a result of the foregoing, income from continuing operations was approximately $0.8 million for the third quarter of fiscal year 2012 versus approximately $7.9 million for the third quarter of fiscal year 2011. Income from continuing operations was approximately $3.2 million for the first nine months of fiscal year 2012 versus approximately $14.6 million for the first nine months of fiscal year 2011.
During fiscal year 2009, we closed our remaining retail store and warehouse operations and reclassified all retail related results as discontinued operations. As a result, we had income from discontinued operations, net of tax, of approximately $0.1 million in the third quarter of fiscal year 2012 compared to approximately $0.2 million in the third quarter of fiscal year 2011. We had income from discontinued operations, net of tax, of approximately $0.4 million for the first nine months of fiscal year 2012 compared to approximately $0.9 million for the first nine months of fiscal year 2011. Two properties classified as discontinued operations were sold during the third quarter of fiscal year 2012, resulting in a gain, net of taxes, of approximately $30,000 compared to approximately $267,000 during the third quarter of fiscal year 2011. Five properties classified as discontinued operations were sold during the first nine months of fiscal year 2012, resulting in a gain, net of taxes, of approximately $80,000 compared to approximately $425,000 during the first nine months of fiscal year 2011.
Income related to noncontrolling interests was approximately $0.5 million and $1.8 million during the third quarter of fiscal years 2012 and 2011, respectively, and approximately $1.5 million and $2.4 million for the nine months ended October 31, 2012 and 2011, respectively, and represents the owners’ (other than us) share of the income of NuGen (fiscal year 2012) and One Earth (fiscal years 2012 and 2011).
As a result of the foregoing, net income attributable to REX common shareholders for the third quarter of fiscal year 2012 was approximately $0.4 million, a decrease of approximately $6.1 million from approximately $6.5 million for the third quarter of fiscal year 2011. Net income attributable to REX common shareholders for the first nine months of fiscal year 2012 was approximately $2.1 million, a decrease of approximately $11.4 million from approximately $13.5 million for the first nine months of fiscal year 2011.
31
Business Segment Results
We have two segments: alternative energy and real estate. The following sections discuss the results of operations for each of our business segments and corporate and other. As discussed in Note 15, our chief operating decision maker (as defined by ASC 280, “ Segment Reporting ”) evaluates the operating performance of our business segments using a measure we call segment profit. Segment profit includes gains and losses on derivative financial instruments. Segment profit excludes income taxes, indirect interest expense, discontinued operations, indirect interest income and certain other items that are included in net income determined in accordance with GAAP. Management believes these are useful financial measures; however, they should not be construed as being more important than other comparable GAAP measures.
Items excluded from segment profit generally result from decisions made by corporate executives. Financing, divestiture and tax structure decisions are generally made by corporate executives. Excluding these items from our business segment performance measure enables us to evaluate business segment operating performance based upon current economic conditions.
The following table sets forth, for the periods indicated, sales and profits by segment (amounts in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
|
||||
|
|
|
|
|
|
|
|
|
|
|
||||
|
Net sales and revenue: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Alternative energy |
|
$ |
178,495 |
|
$ |
84,144 |
|
$ |
481,938 |
|
$ |
238,557 |
|
|
Real estate |
|
|
455 |
|
|
380 |
|
|
1,184 |
|
|
926 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total net sales and revenues |
|
$ |
178,950 |
|
$ |
84,524 |
|
$ |
483,122 |
|
$ |
239,483 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Segment gross profit (loss): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Alternative energy |
|
$ |
3,686 |
|
$ |
8,965 |
|
$ |
16,224 |
|
$ |
14,694 |
|
|
Real estate |
|
|
(39 |
) |
|
53 |
|
|
(117 |
) |
|
(1,171 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total gross profit |
|
$ |
3,647 |
|
$ |
9,018 |
|
$ |
16,107 |
|
$ |
13,523 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Segment profit (loss): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Alternative energy (1) |
|
$ |
1,586 |
|
$ |
12,394 |
|
$ |
6,478 |
|
$ |
22,827 |
|
|
Real estate |
|
|
(91 |
) |
|
7 |
|
|
(277 |
) |
|
(1,306 |
) |
|
Corporate expense |
|
|
(603 |
) |
|
(521 |
) |
|
(1,751 |
) |
|
(1,738 |
) |
|
Interest expense |
|
|
(21 |
) |
|
(25 |
) |
|
(65 |
) |
|
(87 |
) |
|
Income from synthetic fuel partnerships |
|
|
— |
|
|
— |
|
|
— |
|
|
2,883 |
|
|
Investment income |
|
|
19 |
|
|
74 |
|
|
68 |
|
|
289 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations before income taxes |
|
$ |
890 |
|
$ |
11,929 |
|
$ |
4,453 |
|
$ |
22,868 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
Includes income from equity method investments of $1,542,000 and $6,284,000 in the quarters ended October 31, 2012 and 2011, respectively. Includes income from equity |
32
|
|
|
|
method investments of $1,503,000 and $15,827,000 in the nine months ended October 31, 2012 and 2011, respectively. |
|
Alternative Energy
The alternative energy segment includes the consolidated financial results of NuGen (fiscal year 2012) and One Earth (fiscal years 2012 and 2011), our equity method investments in ethanol facilities, the income related to those investments and certain administrative expenses. One Earth became fully operational during the third quarter of fiscal year 2009. Effective November 1, 2011, we obtained a controlling financial interest in NuGen. Thus, we began consolidating the results of NuGen prospectively as of the acquisition date. Prior to November 1, 2011, we used the equity method of accounting to account for the results of NuGen. The following table summarizes sales by product group (amounts in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
|
||||
|
|
|
|
|
|
|
|
|
|
|
||||
|
|
|||||||||||||
|
Ethanol |
|
$ |
132,557 |
|
$ |
69,460 |
|
$ |
366,348 |
|
$ |
194,970 |
|
|
Distillers grains |
|
|
41,027 |
|
|
14,684 |
|
|
102,543 |
|
|
43,587 |
|
|
Other |
|
|
4,911 |
|
|
— |
|
|
13,047 |
|
|
— |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
178,495 |
|
$ |
84,144 |
|
$ |
481,938 |
|
$ |
238,557 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The following table summarizes certain operating data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
|
||||
|
|
|
|
|
|
|
|
|
|
|
||||
|
|
|||||||||||||
|
Average selling price per gallon of ethanol |
|
$ |
2.38 |
|
$ |
2.70 |
|
$ |
2.21 |
|
$ |
2.51 |
|
|
Average selling price per ton of dried distillers grains |
|
$ |
267.63 |
|
$ |
203.13 |
|
$ |
227.07 |
|
$ |
193.47 |
|
|
Average cost per bushel of grain |
|
$ |
7.95 |
|
$ |
7.05 |
|
$ |
6.96 |
|
$ |
6.89 |
|
|
Average cost of natural gas (per mmbtu) |
|
$ |
3.47 |
|
$ |
4.95 |
|
$ |
3.63 |
|
$ |
4.66 |
|
Segment Results – Third Quarter Fiscal Year 2012 Compared to Third Quarter Fiscal Year 2011
Net sales and revenue increased approximately $94.4 million over the third quarter of fiscal year 2011 to approximately $178.5 million in the third quarter of fiscal year 2012, primarily a result of consolidating NuGen in fiscal year 2012. We accounted for the results of NuGen using the equity method of accounting until the fourth quarter of fiscal year 2011, at which time we obtained a controlling financial interest in NuGen, and thus, began consolidating the results. Ethanol sales increased from approximately $69.5 million
33
in the third quarter of fiscal year 2011 to approximately $132.6 million in the third quarter of fiscal year 2012. The average selling price per gallon of ethanol decreased from $2.70 in the third quarter of fiscal year 2011 to $2.38 in the third quarter of fiscal year 2012. This negative pricing impact on sales was more than offset as our ethanol sales were based upon approximately 55.8 million gallons in the third quarter of fiscal year 2012 compared to 25.6 million gallons in the third quarter of fiscal year 2011. The increase in gallons of ethanol sold resulted primarily from including the results of NuGen in the current year but not in the prior year before consolidation. Distillers grains sales increased from approximately $14.7 million in the third quarter of fiscal year 2011 to approximately $41.0 million in the third quarter of fiscal year 2012. Three positive factors impacting distillers grains sales were that the average selling price per ton of dried distillers grains increased from $203.13 in the third quarter of fiscal year 2011 to $267.63 in the third quarter of fiscal year 2012, our dried distillers grains sales were based upon approximately 124,000 tons in the third quarter of fiscal year 2012 compared to approximately 71,000 tons in the third quarter of fiscal year 2011 and that our sales of modified distillers grains increased approximately $7.7 million in the third quarter of fiscal year 2012 compared to the third quarter of fiscal year 2011. The increase in tons of dried distillers grains sold and the increase in modified distillers grains sold resulted primarily from including the results of NuGen in the current year but not in the prior year before consolidation. Non-food grade corn oil sales were approximately $4.5 million in the third quarter of fiscal year 2012. The first quarter of fiscal year 2012 was the first period that our plants produced and sold non-food grade corn oil. We expect that net sales and revenue in future periods will be based upon annual production of 200 million to 230 million gallons of ethanol and 580,000 to 620,000 tons of dried distillers gains. This expectation assumes that One Earth and NuGen will operate at or near nameplate capacity, which is dependent upon the crush spread realized and operational factors.
Gross profit from these sales was approximately $3.7 million during the third quarter of fiscal year 2012 compared to approximately $9.0 million during the third quarter of fiscal year 2011. The crush spread for the third quarter of fiscal year 2012 was approximately ($0.46) per gallon of ethanol sold compared to the third quarter of fiscal year 2011 which was approximately $0.18 per gallon of ethanol sold. This trend was offset by the sales of distillers grains and non-food grade corn oil in the third quarter of fiscal year 2012. In addition, gross profit increased, in part as a result of including the results of NuGen in the current year but not in the prior year before consolidation. Grain accounted for approximately 89.1% ($155.7 million) of our cost of sales during the third quarter of fiscal year 2012 compared to approximately 84.4% ($63.7 million) during the third quarter of fiscal year 2011. Natural gas accounted for approximately 3.1% ($5.5 million) of our cost of sales during the third quarter of fiscal year 2012 compared to approximately 4.7% ($3.5 million) during the third quarter of fiscal year 2011. Given the inherent volatility in ethanol, distillers grains, non-food grade corn oil, grain and natural gas prices, we cannot predict the likelihood that the spread between ethanol, distillers grains, non-food grade corn oil and grain prices in future periods will be favorable or consistent compared to historical periods.
34
We attempt to match quantities of ethanol and distillers grains sale contracts with an appropriate quantity of grain purchase contracts over a given period of time when we can obtain an adequate margin resulting from the crush spread inherent in the contracts we have executed. However, the market for future ethanol sales contracts is not a mature market. Consequently, we generally execute fixed price contracts for no more than three months into the future at any given time. As a result of the relatively short period of time our contracts cover, we generally cannot predict the future movements in the crush spread for more than three months. Less than 1% of our forecasted ethanol, approximately 6% of our forecasted distillers grains and approximately 12% of our forecasted non-food grade corn oil production during the next 12 months have been sold under fixed-price contracts. The effect of a 10% adverse change in the price of ethanol, distillers grains and non-food grade corn oil from the current pricing would result in a decrease in annual revenues in fiscal year 2012 of approximately $64.8 million. Similarly, approximately 1% of our estimated corn usage for the next 12 months was subject to fixed-price contracts. The effect of a 10% adverse change in the price of corn from current pricing would result in an increase in annual cost of goods sold in fiscal year 2012 of approximately $55.7 million.
Selling, general and administrative expenses were approximately $2.3 million in the third quarter of fiscal year 2012, a $0.5 million increase from approximately $1.8 million in the third quarter of fiscal year 2011. The increase is primarily a result of including the results of NuGen in the current year. NuGen incurred approximately $1.3 million of expenses in the third quarter of fiscal year 2012. This increase was partially offset by a decrease in executive incentive compensation of approximately $0.6 million, a result of decreased segment profitability. We expect selling, general and administrative expenses to remain consistent with the third quarter of fiscal year 2012 results in future periods.
Interest expense increased approximately $0.6 million in the third quarter of fiscal year 2012 from the third quarter of fiscal year 2011 to approximately $1.2 million. This increase is primarily a result of consolidating NuGen beginning November 1, 2011 versus using the equity method of accounting for NuGen prior to November 1, 2011. Based on current interest rates and debt levels, we expect interest expense in future quarters to be consistent with the third quarter of fiscal year 2012 amount.
Income from equity method investments includes Big River, Patriot and NuGen for fiscal year 2011 and Big River and Patriot for fiscal year 2012 as we began consolidating the results of NuGen effective November 1, 2011. We recognized income from equity method investments of approximately $1.5 million in the third quarter of fiscal year 2012 compared to approximately $6.3 million in the third quarter of fiscal year 2011. We recognized approximately $0.5 million of loss from Big River in the third quarter of fiscal year 2012 compared to approximately $1.6 million of income in the third quarter of fiscal year 2011. We recognized approximately $2.0 million of income from Patriot in the third quarter of fiscal years 2012 and 2011. We recognized approximately $2.7 million of income from NuGen in the third quarter of fiscal year 2011. In general, Big River experienced lower crush spreads in the third quarter of fiscal year 2012 relative to the third quarter of fiscal year 2011, which is consistent with industry trends. Patriot
35
experienced higher crush spreads in the third quarter of fiscal year 2012 relative to industry trends, primarily a result of discrete opportunistic grain purchases which we believe will be non-recurring in future periods. Given the inherent volatility in the factors that affect the crush spread, we cannot predict the likelihood that the trend with respect to income from equity method investments will be comparable in future periods.
Losses on derivative financial instruments held by One Earth were approximately $0.1 million in the third quarter of fiscal year 2012 compared to approximately $0.5 million in the third quarter of fiscal year 2011. Since the gains or losses on these derivative financial instruments are primarily a function of the movement in interest rates, we cannot predict the likelihood that such gains or losses in future periods will be consistent with current year results.
As a result of the factors discussed above, segment profit decreased to approximately $1.6 million in the third quarter of fiscal year 2012 compared to approximately $12.4 million in the third quarter of fiscal year 2011.
Segment Results – Nine Months Ended October 31, 2012 Compared to Nine Months Ended October 31, 2011
Net sales and revenue increased approximately $243.4 million to approximately $481.9 million, primarily a result of consolidating NuGen in fiscal year 2012. We accounted for the results of NuGen using the equity method of accounting until the fourth quarter of fiscal year 2011, at which time we obtained a controlling financial interest in NuGen, and thus, began consolidating the results. Ethanol sales increased from approximately $195.0 million in the first nine months of fiscal year 2011 to approximately $366.3 million in the first nine months of fiscal year 2012. The average selling price per gallon of ethanol decreased from $2.51 in the first nine months of fiscal year 2011 to $2.21 in the first nine months of fiscal year 2012. This negative impact on sales was more than offset as our ethanol sales were based upon approximately 165.6 million gallons in the first nine months of fiscal year 2012 compared to 77.4 million gallons in the first nine months of fiscal year 2011. The increase in gallons of ethanol sold resulted primarily from including the results of NuGen in the current year but not in the prior year before consolidation. Distillers grains sales increased from approximately $43.6 million in the first nine months of fiscal year 2011 to approximately $102.5 million in the first nine month of fiscal year 2012. Three positive factors impacting distillers grains sales were that the average selling price per ton of dried distillers grains increased from $193.47 in the first nine months of fiscal year 2011 to $227.07 in the first nine months of fiscal year 2012, our dried distillers grains sales were based upon approximately 374,000 tons in the first nine months of fiscal year 2012 compared to approximately 220,000 tons in the first nine months of fiscal year 2011 and that our sales of modified distillers grains increased approximately $17.2 million for the first nine months of fiscal year 2012 compared to the first nine months of fiscal year 2011. The increase in tons of dried distillers grains sold resulted primarily from including the results of NuGen in the current year but not in the prior year before consolidation. Non-food grade corn oil sales were approximately $11.8
36
million in the first nine months of fiscal year 2012. The first quarter of fiscal year 2012 was the first period that our plants produced and sold non-food grade corn oil.
Gross profit from these sales was approximately $16.2 million during the first nine months of fiscal year 2012 compared to approximately $14.7 million during the first nine months of fiscal year 2011. The crush spread for the first nine months of fiscal year 2012 was approximately ($0.28) per gallon of ethanol sold compared to the first nine months of fiscal year 2011 which was approximately $0.05 per gallon of ethanol sold. This trend was partially offset by the sales of distillers grains and non-food grade corn oil in the first nine months of fiscal year 2012. In addition, gross profit increased, in part, as a result of including the results of NuGen in the current year but not in the prior year before consolidation. Grain accounted for approximately 87.1% ($405.4 million) of our cost of sales during the first nine months of fiscal year 2012 compared to approximately 84.9% ($189.5 million) during the first nine months of fiscal year 2011. Natural gas accounted for approximately 3.6% ($16.9 million) of our cost of sales during the first nine months of fiscal year 2012 compared to approximately 4.6% ($10.3 million) during the first nine months of fiscal year 2011.
Selling, general and administrative expenses were approximately $7.2 million in the first nine months of fiscal year 2012, a $2.5 million increase from approximately $4.7 million in the first nine months of fiscal year 2011. The increase is primarily a result of including the results of NuGen in the current year. NuGen incurred approximately $4.2 million of expenses in the first nine months of fiscal year 2012. This increase was partially offset by a decrease in executive incentive compensation of approximately $1.1 million, a result of decreased segment profitability.
Interest expense increased approximately $1.8 million in the first nine months of fiscal year 2012 from the first nine months of fiscal year 2011 to approximately $3.7 million. This increase is primarily a result of consolidating NuGen beginning November 1, 2011, versus using the equity method of accounting for NuGen prior to November 1, 2011.
Income from equity method investments includes Big River, Patriot and NuGen for fiscal year 2011 and Big River and Patriot for fiscal year 2012 as we began consolidating the results of NuGen effective November 1, 2011. We recognized income from equity method investments of approximately $1.5 million in the first nine months of fiscal year 2012 compared to approximately $15.8 million in the first nine months of fiscal year 2011. We recognized approximately $0.2 million of income from Big River in the first nine months of fiscal year 2012 compared to approximately $4.4 million in the first nine months of fiscal year 2011. We recognized approximately $1.3 million of income from Patriot in the first nine months of fiscal year 2012 compared to approximately $3.4 million in the first nine months of fiscal year 2011. We recognized approximately $8.1 million of income from NuGen in the first nine months of fiscal year 2011. In general, Big River and Patriot experienced lower crush spreads in the first nine months of fiscal year 2012 relative to the first nine months of fiscal year 2011, which is consistent with industry trends.
37
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Losses on derivative financial instruments held by One Earth were approximately $0.4 million in the first nine months of fiscal year 2012 compared to approximately $1.2 million in the first nine months of fiscal year 2011. |
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As a result of the factors discussed above, segment profit decreased to approximately $6.5 million in the first nine months of fiscal year 2012 compared to approximately $22.8 million in the first nine months of fiscal year 2011. |
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Real Estate
The real estate segment includes all owned real estate including those previously used as retail store and distribution center operations, our real estate leasing activities and certain administrative expenses. It excludes results from discontinued operations.
At October 31, 2012, we have lease agreements, as landlord, for six owned former retail stores (77,000 square feet leased). We have 12 owned former retail stores (152,000 square feet) that are vacant at October 31, 2012. We are marketing these vacant properties for lease or sale. In addition, one owned former distribution center is partially leased (356,000 square feet), partially occupied by our corporate office personnel (10,000 square feet) and partially vacant (111,000 square feet).
Segment Results – Third Quarter Fiscal Year 2012 Compared to Third Quarter Fiscal Year 2011
Net sales and revenue of $455,000 increased $75,000 over the prior year amount of $380,000. The increase results primarily from two additional properties and additional space in our distribution center leased during fiscal year 2012 compared to fiscal year 2011. We expect lease revenue for the remainder of fiscal year 2012 to be consistent with the third quarter of fiscal year 2012 based upon leases currently executed.
Gross loss in the third quarter of fiscal year 2012 was $39,000 compared to gross profit of $53,000 in the third quarter of fiscal year 2011. The increase in gross loss compared to the prior year is primarily a result of impairment charges, incurred in fiscal year 2012, of approximately $136,000 related to a vacant property. We expect gross profit or loss for the remainder of fiscal year 2012 to be insignificant based upon leases currently executed.
As a result of the factors discussed above, the segment loss was $91,000 in the third quarter of fiscal year 2012 compared to a segment profit of $7,000 in the third quarter of fiscal year 2011.
Segment Results – Nine Months Ended October 31, 2012 Compared to Nine Months Ended October 31, 2011
Net sales and revenue of $1,184,000 increased $258,000 over the prior year amount of $926,000. The increase results primarily from three additional properties leased for the entire period in fiscal year 2012 compared to fiscal year 2011 and additional space in our distribution
38
center leased during fiscal year 2012. We expect lease revenue for the remainder of fiscal year 2012 to be consistent with the first nine months of fiscal year 2012 based upon leases currently executed.
Gross loss in the first nine months of fiscal year 2012 was $117,000 compared to $1,171,000 in the first nine months of fiscal year 2011. The decrease in gross loss compared to the prior year is primarily a result of impairment charges, incurred in fiscal year 2011, of approximately $1,164,000 primarily related to a former distribution center, a portion of which is used as our corporate headquarters. We expect gross profit or loss for the remainder of fiscal year 2012 to be insignificant based upon leases currently executed.
As a result of the factors discussed above, segment loss decreased to $277,000 in the first nine months of fiscal year 2012 from $1,306,000 in the first nine months of fiscal year 2011.
Corporate and Other
Corporate and other includes certain administrative expenses of the corporate headquarters, interest expense and investment income not directly allocated to the alternative energy or real estate segments.
Corporate and Other Results –Third Quarter Fiscal Year 2012 Compared to Third Quarter Fiscal Year 2011
Selling, general and administrative expenses were approximately $0.6 million in the third quarter of fiscal year 2012 consistent with the third quarter of fiscal year 2011. We expect selling, general and administrative expenses for the remainder of fiscal year 2012 to be consistent with the current year third quarter results.
Interest income was $19,000 in the third quarter of fiscal year 2012 compared to $74,000 in the third quarter of fiscal year 2011. The decrease is primarily a result of lower levels of excess cash invested and lower yields earned in the current year. We expect interest income for the remainder of fiscal year 2012 to be consistent with the current year third quarter results.
Interest expense was consistent with the prior year amount.
Corporate and Other Results – Nine Months Ended October 31, 2012 Compared to Nine Months Ended October 31, 2011
Selling, general and administrative expenses were approximately $1.8 million in the first nine months of fiscal year 2012 consistent with the first nine months of fiscal year 2011. We expect selling, general and administrative expenses for the remainder of fiscal year 2012 to be consistent with the current year third quarter results.
Interest income was $68,000 in the first nine months of fiscal year 2012 compared to $289,000 in the first nine months of fiscal year 2011. The decrease is primarily a result of lower levels of excess cash invested and lower yields earned in the current year. We expect interest
39
income for the remainder of fiscal year 2012 to be consistent with the current year third quarter results.
Interest expense was consistent with the prior year amount.
Liquidity and Capital Resources
Net cash provided by operating activities was approximately $13.2 million for the first nine months of fiscal year 2012, compared to approximately $22.5 million for the first nine months of fiscal year 2011. For the first nine months of fiscal year 2012, cash was provided by net income of approximately $3.7 million, adjusted for non-cash items of approximately $10.3 million, which consisted of depreciation and amortization, impairment charges, income from equity method investments, loss on disposal of real estate and property and equipment, deferred income, losses on derivative financial instruments and the deferred income tax provision. Dividends received from our equity method investees were approximately $2.0 million in the first nine months of fiscal year 2012. An increase in accounts receivable represented a use of cash of approximately $5.0 million, primarily a result of normal variations in production and sales levels and the timing of customer payments received. Other liabilities used cash of approximately $4.4 million, primarily a result of the payment of incentive compensation that was accrued at year end. An increase in accounts payable provided cash of approximately $3.0 million, which is primarily a result of the timing of vendor shipments of inventory and vendor payments. A decrease in inventory provided cash of approximately $2.0 million, which is primarily a result of normal fluctuations in production and sales levels. A decrease in other assets provided cash of approximately $1.5 million, which is primarily a result of income tax refunds. We do not expect to receive significant tax refunds for the remainder of fiscal year 2012.
Net cash provided by operating activities was approximately $22.5 million for the first nine months of fiscal year 2011. For the first nine months of fiscal year 2011, cash was provided by net income of $15.9 million, adjusted for non-cash items of approximately $(5.8) million, which consisted of depreciation and amortization, impairment charges, income from equity method and synthetic fuel investments, gain on disposal of real estate and property and equipment, deferred income, losses on derivative financial instruments, the deferred income tax provision and other items. Dividends received from our equity method investees were $2.3 million in the first nine months of fiscal year 2011. In addition, prepaid expense and other current and long term assets provided cash of $9.5 million, primarily a result of federal income tax refunds received. Accounts receivable provided cash of $2.3 million, a result of normal variations in production and sales levels and a change in the payment patterns of our customer base. Other liabilities provided cash of approximately $2.0 million, generally a result of normal variations in accrued liabilities. The primary uses of cash were an increase in inventory of $2.3 million and a decrease in accounts payable of $1.5 million. These fluctuations were the result of normal variations in production, purchasing and grain prices.
At October 31, 2012, working capital was approximately $89.1 million compared to approximately $89.8 million at January 31, 2012. The decrease is primarily a result of financing activities (debt service and treasury stock repurchases) exceeding our operating cash flows. The
40
ratio of current assets to current liabilities was 3.7 to 1 at October 31, 2012 and 3.4 to 1 at January 31, 2012.
Cash of approximately $0.6 million was provided by investing activities for the first nine months of fiscal year 2012, compared to approximately $5.6 during the first nine months of fiscal year 2011. During the first nine months of fiscal year 2012, we had capital expenditures of approximately $2.5 million, primarily related to improvements at the One Earth ethanol plant. We do not expect to spend significant amounts for capital expenditures during the remainder of fiscal year 2012. We received approximately $2.3 million as proceeds from the sale of four real estate properties during the first nine months of fiscal year 2012. We also received approximately $0.9 million as we were able to reduce the amount of our restricted investments on deposit with the state of Florida to secure our extended service plan obligations.
Cash of approximately $5.6 million was provided by investing activities for the first nine months of fiscal year 2011. During the first nine months of fiscal year 2011, we had capital expenditures of approximately $0.7 million, primarily related to improvements at the One Earth ethanol plant. During the first nine months of fiscal year 2011, we received a payment of $2.8 million related to the final settlement of a synthetic fuel partnership sale. We received approximately $3.4 million as proceeds from the sale of six real estate properties and certain ethanol related equipment during the first nine months of fiscal year 2011.
Cash used in financing activities totaled approximately $20.7 million for the first nine months of fiscal year 2012 compared to approximately $32.4 million for the first nine months of fiscal year 2011. Cash was used by debt payments of approximately $15.2 million, primarily on One Earth’s and NuGen’s term loans. We used cash of approximately $2.1 million to purchase shares from and pay dividends to noncontrolling members of NuGen and One Earth. We do not expect such payments to noncontrolling members of NuGen or One Earth to increase significantly for the remainder of fiscal year 2012. Stock option activity generated cash of approximately $0.4 million. In addition, cash of $3.8 million was used to repurchase approximately 213,532 shares of our common stock in open market transactions.
Cash used in financing activities totaled approximately $32.4 million for the first nine months of fiscal year 2011. Cash of approximately $1.3 million was used to reduce the contingent consideration liability related to our acquisition of NuGen. Cash was used by debt payments of $8.2 million, primarily on One Earth’s term loans. Stock option activity generated cash of $0.3 million. We used $21.2 million to repurchase 1,249,801 shares of our common stock in open market transactions during the first nine months of fiscal year 2011. We used cash of $2.0 million to purchase shares from and pay dividends to noncontrolling members of One Earth.
In September 2007, One Earth entered into a $111,000,000 financing agreement consisting of a construction loan agreement for $100,000,000 together with a $10,000,000 revolving loan and a $1,000,000 letter of credit with First National Bank of Omaha. The construction loan was converted into a term loan on July 31, 2009. The term loan bears interest at variable interest rates ranging from LIBOR plus 280 basis points to LIBOR plus 300 basis points (3.3% to 3.5% at October 31, 2012). Beginning with the first quarterly payment on October 8, 2009, payments are due in 19 quarterly payments of principal plus accrued interest with the principal portion calculated based on a 120 month amortization schedule.
41
One final installment will be required on the maturity date (July 31, 2014) for the remaining unpaid principal balance with accrued interest. This debt is recourse only to One Earth and not to REX American Resources Corporation or any of its other subsidiaries.
Borrowings are secured by all property of One Earth. As of October 31, 2012, approximately $58.2 million was outstanding on the term loan. One Earth is also subject to certain financial covenants under the loan agreement. The specific covenant requirements, descriptions and calculated ratios and amounts are as follows:
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Maintain a fixed charge coverage ratio, measured on a rolling four quarters trailing basis, of at least 1.10 to 1.00. |
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This ratio is computed by dividing adjusted EBITDA (EBITDA less taxes, capital expenditures and distributions paid to members) by scheduled principal and interest payments. At October 31, 2012, the fixed charge coverage ratio was 1.23 to 1.00. |
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Maintain working capital of at least $10 million. |
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Working capital is defined as total current assets (less investments in or other amounts due from any member, manager, employee or any other person or entity related to or affiliated with One Earth) less total current liabilities. At October 31, 2012, working capital was approximately $23.8 million. |
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Capital expenditures are limited to $3.0 million annually. |
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For the nine months ended October 31, 2012, capital expenditures were approximately $1.6 million. |
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One Earth was in compliance with all covenants at October 31, 2012. |
In November 2011, NuGen entered into a $65,000,000 financing agreement consisting of a term loan agreement for $55,000,000 and a $10,000,000 revolving loan with First National Bank of Omaha. The term loan bears interest at a variable interest rate of LIBOR plus 325 basis points, subject to a 4% floor (4% at October 31, 2012). Beginning with the first quarterly payment on February 1, 2012, payments are due in 19 quarterly payments of principal plus accrued interest with the principal portion calculated based on a 120 month amortization schedule. One final installment will be required on the maturity date (October 31, 2016) for the remaining unpaid principal balance with accrued interest. This debt is recourse only to NuGen and not to REX American Resources Corporation or any of its other subsidiaries.
Borrowings are secured by all property of NuGen. As of October 31, 2012, approximately $49.5 million was outstanding on the term loan. NuGen is also subject to certain financial covenants under the loan agreement. The specific covenant requirements, descriptions and calculated ratios and amounts are as follows:
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Maintain working capital of at least $10 million. |
42
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Working capital is defined as total current assets (less investments in or other amounts due from any member, manager, employee or any other person or entity related to or affiliated with NuGen) less total current liabilities. At October 31, 2012, working capital was approximately $16.4 million. |
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Maintain a fixed charge coverage ratio of at least 1.10 to 1.00 (beginning with the quarter and year ended January 31, 2013) |
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This ratio is computed by dividing adjusted EBITDA (EBITDA less taxes, capital expenditures and distributions paid to members) by scheduled principal and interest payments. This covenant was not applicable at October 31, 2012. |
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Capital expenditures are limited to $2.5 million annually, except for fiscal year 2012 which has a limit of $6.0 million. |
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For the nine months ended October 31, 2012, capital expenditures were approximately $0.3 million. |
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NuGen was in compliance with all covenants, as applicable, at October 31, 2012. |
We believe we have sufficient working capital and credit availability to fund our commitments and to maintain our operations at their current levels for the next twelve months and foreseeable future.
Forward-Looking Statements
This Form 10-Q contains or may contain forward-looking statements as defined in the Private Securities Litigation Reform Act of 1995. Such statements can be identified by use of forward-looking terminology such as “may,” “expect,” “believe,” “estimate,” “anticipate” or “continue” or the negative thereof or other variations thereon or comparable terminology. Readers are cautioned that there are risks and uncertainties that could cause actual events or results to differ materially from those referred to in such forward-looking statements. These risks and uncertainties include the risk factors set forth from time to time in the Company’s filings with the Securities and Exchange Commission and include among other things: the impact of legislative changes, the price volatility and availability of corn, distillers grains, ethanol, non-food grade corn oil, gasoline, natural gas, ethanol plants operating efficiently and according to forecasts and projections, changes in the national or regional economies, weather, the effects of terrorism or acts of war and changes in real estate market conditions. The Company does not intend to update publicly any forward-looking statements except as required by law. Other factors that could cause actual results to differ materially from those in the forward-looking statements are set forth in Item 1A of the Company’s Annual Report on Form 10-K for the fiscal year ended January 31, 2012 (File No. 001-09097).
I tem 3. Quantitative and Qualitative Disclosures About Market Risk
We are exposed to the impact of market fluctuations associated with interest rates and commodity prices as discussed below.
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Interest Rate Risk
We are exposed to market risk from changes in interest rates. Interest rate risk related to interest income is immaterial. Exposure to interest rate risk results primarily from holding term and revolving loans that bear variable interest rates. Specifically, we have approximately $107.7 million outstanding in debt as of October 31, 2012, that is variable-rate. Of this amount, approximately $38.8 million is fixed by an interest rate swap. Interest rates on our variable-rate debt are determined based upon the market interest rate of LIBOR plus 280 to 325 basis points. A 10% adverse change (for example from 3.0% to 3.3%) in market interest rates would increase our interest cost on such debt by approximately $298,000 over the term of the debt. However, this change would be greater should LIBOR rates exceed 0.75%, as the floor interest rate of NuGen’s debt is the greater of 4% or LIBOR plus 325 basis points.
One Earth entered into a forward interest rate swap in the notional amount of $50.0 million with the First National Bank of Omaha during fiscal year 2007. The swap fixed the variable interest rate of a portion of One Earth’s term loan at 7.9%. The swap settlements commenced on July 31, 2009 and terminate on July 8, 2014. A hypothetical 10% change (for example, from 4.0% to 3.6%) in market interest rates at quarter end would change the fair value of the interest rate swap by approximately $0.3 million.
Commodity Price Risk
We manage a portion of our risk with respect to the volatility of commodity prices inherent in the ethanol industry by using forward purchase and sale contracts. At October 31, 2012, One Earth and NuGen combined have purchase commitments for approximately 18.9 million bushels of corn, the principal raw material for their ethanol plants. One Earth and NuGen expect to take delivery of the corn through March 2013. At October 31, 2012, One Earth and NuGen have combined sales commitments for approximately 45.1 million gallons of ethanol, approximately 49,000 tons of distillers grains and approximately 4.7 million pounds of non-food grade corn oil. One Earth and NuGen expect to deliver the ethanol, distillers grains and non-food grade corn oil through March 2013. Less than 1% of our forecasted ethanol sales during the next 12 months have been sold under fixed-price contracts. As a result, the effect of a 10% adverse move in the price of ethanol from the current pricing would result in a decrease in annual revenues of approximately $45.9 million for the remaining forecasted ethanol sales. Approximately 6% of our forecasted distillers grains sales during the next 12 months have been sold under fixed-price contracts. As a result, the effect of a 10% adverse move in the price of distillers grains from the current pricing would result in a decrease in annual revenues of approximately $17.6 million for the remaining forecasted distillers grains sales. Approximately 12% of our forecasted non-food grade corn oil sales during the next 12 months have been sold under fixed-price contracts. As a result, the effect of a 10% adverse move in the price of non-food grade corn oil from the current pricing would result in a decrease in annual revenues of approximately $1.3 million for the remaining forecasted non-food grade corn oil sales. Similarly, approximately 1% of our estimated corn usage for the next 12 month was subject to fixed-price contracts. As a result, the effect of a 10% adverse move in the price of corn for current pricing would result in an increase in annual cost of goods sold of approximately $55.7 million for the remaining forecasted corn usage.
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I tem 4. Controls and Procedures
Our management evaluated, with the participation of our Chief Executive Officer and Chief Financial Officer, the effectiveness of our disclosure controls and procedures, as of the end of the period covered by this report. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures are effective to ensure that information required to be disclosed by us in the reports that we file or submit under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms and is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.
There were no changes in our internal control over financial reporting that occurred during our last fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
We are not party to any legal proceedings that we believe would, individually or in the aggregate, have a material adverse effect on our financial condition, results of operations or cash flows.
During the quarter ended October 31, 2012, there have been no material changes to the risk factors discussed in our Annual Report on Form 10-K for the year ended January 31, 2012.
I tem 2. Unregistered Sales of Equity Securities and Use of Proceeds
Dividend Policy
REX did not pay dividends in the current or prior years. We currently have no restrictions on the payment of dividends. Our consolidated and unconsolidated ethanol subsidiaries have certain restrictions on their ability to pay dividends to us. During the first nine months of fiscal year 2012, One Earth paid dividends of $5,490,000. Of this amount, $1,429,000 was paid to noncontrolling interests unit holders and $4,061,000 was paid to REX American Resources Corporation. During the first nine months of fiscal year 2012, NuGen paid dividends of approximately $80,000 to noncontrolling interests unit holders.
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Issuer Purchases of Equity Securities
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Period |
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Total Number
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Average
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Total Number of
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Maximum Number
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August 1-31, 2012 |
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20,912 |
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$ |
18.24 |
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20,912 |
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504,061 |
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September 1-30, 2012 |
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19,529 |
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17.83 |
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19,529 |
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484,532 |
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October 1-31, 2012 |
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35,609 |
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17.81 |
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35,609 |
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448,923 |
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Total |
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76,050 |
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$ |
17.93 |
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76,050 |
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448,923 |
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(1) |
On August 2, 2012, our Board of Directors increased our share repurchase authorization by an additional 500,000 shares. At October 31, 2012, a total of 448,923 shares remained available to purchase under this authorization. |
I tem 3. Defaults upon Senior Securities
None
I tem 4. Mine Safety Disclosures
None
None
The following exhibits are filed with this report:
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Rule 13a-14(a)/15d-14(a) Certifications |
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32 |
Section 1350 Certifications |
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101 |
The following information from REX American Resources Corporation Quarterly Report on Form 10-Q for the quarter ended October 31, 2012, formatted in XBRL: (i) Consolidated Condensed Balance Sheets, (ii) Consolidated Condensed Statements of Operations, (iii) Consolidated Condensed Statements of Equity, (iv) Consolidated Condensed Statements of Cash Flows and (v) Notes to Consolidated Condensed Financial Statements. |
46
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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REX American Resources Corporation |
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Registrant |
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Signature |
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Title |
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/s/ Stuart A. Rose |
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Chairman of the Board
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December 6, 2012 |
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(Stuart A. Rose) |
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/s/ Douglas L. Bruggeman |
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Vice President, Finance and Treasurer
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December 6, 2012 |
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(Douglas L. Bruggeman) |
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No information found
* THE VALUE IS THE MARKET VALUE AS OF THE LAST DAY OF THE QUARTER FOR WHICH THE 13F WAS FILED.
| FUND | NUMBER OF SHARES | VALUE ($) | PUT OR CALL |
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| DIRECTORS | AGE | BIO | OTHER DIRECTOR MEMBERSHIPS |
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No information found
No Customers Found
No Suppliers Found
Price
Yield
| Owner | Position | Direct Shares | Indirect Shares |
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