UNITED STATES SECURITIES AND
EXCHANGE COMMISSION
Washington, D.C.
20549
Form 10-Q
|
|
|
(Mark One)
|
|
|
|
þ
|
|
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
|
|
|
For the quarterly period ended
September 30, 2007
|
OR
|
o
|
|
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
|
|
|
For the transition period
from to
|
Commission File Number:
001-33203
US BioEnergy
Corporation
(Exact name of Registrant as
specified in its charter)
|
|
|
South Dakota
|
|
20-1811472
|
(State or other jurisdiction
of
|
|
(I.R.S. Employer
|
incorporation or
organization)
|
|
Identification No.)
|
|
|
|
5500 Cenex Drive
Inver Grove Heights, Minnesota
|
|
55077
(Zip Code)
|
(Address of principal executive
offices)
|
|
|
Registrants telephone number, including area code:
(651) 554-5000
Indicate by check mark whether the registrant (1) has filed
all reports required to be filed by Section 13 or 15(d) of
the Securities Exchange Act of 1934 during the preceding
12 months (or for such shorter period that the registrant
was required to file such reports), and (2) has been
subject to such filing requirements for the past
90 days. Yes
þ
No
o
Indicate by check mark whether the registrant is a large
accelerated filer, an accelerated filer, or a
non-accelerated
filer. See definition of accelerated filer and large
accelerated filer in
Rule 12b-2
of the Exchange Act. (Check one):
Large accelerated
filer
o
Accelerated
filer
o
Non-accelerated
filer
þ
Indicate by check mark whether the registrant is a shell company
(as defined in
Rule 12b-2
of the Exchange
Act). Yes
o
No
þ
The number of shares of the registrants common stock,
$0.01 par value per share, outstanding on October 31,
2007, was 79,622,690.
US
BioEnergy Corporation
TABLE OF
CONTENTS
2
PART I.
FINANCIAL INFORMATION
|
|
ITEM 1:
|
FINANCIAL
STATEMENTS
|
Condensed
Consolidated Balance Sheets
(In
thousands, except per share data)
|
|
|
|
|
|
|
|
|
|
|
September 30,
|
|
|
December 31,
|
|
|
|
2007
|
|
|
2006
|
|
|
|
(Unaudited)
|
|
|
|
|
|
ASSETS
|
Current Assets
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$
|
79,729
|
|
|
$
|
170,099
|
|
Receivables
|
|
|
49,555
|
|
|
|
40,958
|
|
Inventories
|
|
|
23,004
|
|
|
|
28,420
|
|
Derivative financial instruments
|
|
|
2,515
|
|
|
|
7,144
|
|
Prepaid expenses
|
|
|
4,007
|
|
|
|
3,572
|
|
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
158,810
|
|
|
|
250,193
|
|
|
|
|
|
|
|
|
|
|
Other Assets
|
|
|
|
|
|
|
|
|
Deposits
|
|
|
6,967
|
|
|
|
4,307
|
|
Investment in equity of unconsolidated subsidiary
|
|
|
3,691
|
|
|
|
1,509
|
|
Goodwill
|
|
|
63,991
|
|
|
|
65,489
|
|
Intangible assets
|
|
|
5,944
|
|
|
|
3,174
|
|
Other assets
|
|
|
200
|
|
|
|
304
|
|
|
|
|
|
|
|
|
|
|
|
|
|
80,793
|
|
|
|
74,783
|
|
|
|
|
|
|
|
|
|
|
Property and equipment, net
|
|
|
849,730
|
|
|
|
408,814
|
|
|
|
|
|
|
|
|
|
|
Total assets
|
|
$
|
1,089,333
|
|
|
$
|
733,790
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND SHAREHOLDERS EQUITY
|
Liabilities
|
|
|
|
|
|
|
|
|
Current maturities of long-term debt
|
|
$
|
15,819
|
|
|
$
|
8,131
|
|
Checks written on controlled disbursement accounts
|
|
|
|
|
|
|
13,270
|
|
Notes payable
|
|
|
|
|
|
|
1,815
|
|
Accounts payable
|
|
|
46,851
|
|
|
|
47,163
|
|
Accrued expenses
|
|
|
15,467
|
|
|
|
4,938
|
|
Deferred income tax liability
|
|
|
1,217
|
|
|
|
2,913
|
|
Other current liabilities
|
|
|
238
|
|
|
|
3,955
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
79,592
|
|
|
|
82,185
|
|
|
|
|
|
|
|
|
|
|
Long-term debt
|
|
|
331,244
|
|
|
|
140,128
|
|
Deferred income taxes
|
|
|
43,047
|
|
|
|
27,099
|
|
Long-term income taxes payable
|
|
|
331
|
|
|
|
|
|
Minority interest in subsidiary
|
|
|
3,942
|
|
|
|
|
|
Other long-term liabilities
|
|
|
567
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total long-term liabilities
|
|
|
379,131
|
|
|
|
167,227
|
|
|
|
|
|
|
|
|
|
|
Total liabilities
|
|
|
458,723
|
|
|
|
249,412
|
|
|
|
|
|
|
|
|
|
|
Commitments and Contingencies
|
|
|
|
|
|
|
|
|
Shareholders Equity
|
|
|
|
|
|
|
|
|
Preferred stock, $0.01 par value, authorized
75,000,000 shares, issued none
|
|
|
|
|
|
|
|
|
Common stock, $0.01 par value, authorized
750,000,000 shares; 79,616,190 and 67,968,885 shares
issued and outstanding as of September 30, 2007, and
December 31, 2006, respectively
|
|
|
796
|
|
|
|
679
|
|
Additional paid-in capital
|
|
|
588,862
|
|
|
|
467,552
|
|
Retained earnings
|
|
|
40,952
|
|
|
|
16,147
|
|
|
|
|
|
|
|
|
|
|
Total shareholders equity
|
|
|
630,610
|
|
|
|
484,378
|
|
|
|
|
|
|
|
|
|
|
Total liabilities and shareholders equity
|
|
$
|
1,089,333
|
|
|
$
|
733,790
|
|
|
|
|
|
|
|
|
|
|
See notes to condensed consolidated financial statements
3
Condensed
Consolidated Statements of Operations
(In
thousands, except per share data)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
September 30,
|
|
|
|
2007
|
|
|
2006
|
|
|
2007
|
|
|
2006
|
|
|
|
(Unaudited)
|
|
|
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Product sales
|
|
$
|
148,337
|
|
|
$
|
30,597
|
|
|
$
|
427,518
|
|
|
$
|
51,914
|
|
Services and commissions
|
|
|
1,480
|
|
|
|
1,135
|
|
|
|
6,345
|
|
|
|
5,665
|
|
Other revenues
|
|
|
228
|
|
|
|
1,518
|
|
|
|
2,803
|
|
|
|
2,785
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
|
150,045
|
|
|
|
33,250
|
|
|
|
436,666
|
|
|
|
60,364
|
|
Cost of goods sold:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of product sales
|
|
|
120,459
|
|
|
|
22,335
|
|
|
|
367,849
|
|
|
|
39,478
|
|
Cost of services and commissions
|
|
|
801
|
|
|
|
1,333
|
|
|
|
2,679
|
|
|
|
4,291
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total cost of goods sold
|
|
|
121,260
|
|
|
|
23,668
|
|
|
|
370,528
|
|
|
|
43,769
|
|
Gross profit
|
|
|
28,785
|
|
|
|
9,582
|
|
|
|
66,138
|
|
|
|
16,595
|
|
Selling, general and administrative expenses
|
|
|
10,846
|
|
|
|
7,233
|
|
|
|
28,612
|
|
|
|
17,725
|
|
Loss on impairment of assets
|
|
|
2,471
|
|
|
|
|
|
|
|
2,471
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income (loss)
|
|
|
15,468
|
|
|
|
2,349
|
|
|
|
35,055
|
|
|
|
(1,130
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(1,425
|
)
|
|
|
(928
|
)
|
|
|
(8,238
|
)
|
|
|
(1,370
|
)
|
Interest income
|
|
|
1,257
|
|
|
|
694
|
|
|
|
5,643
|
|
|
|
1,624
|
|
Other income
|
|
|
7
|
|
|
|
16
|
|
|
|
4,022
|
|
|
|
38
|
|
Equity in net income (loss) of unconsolidated subsidiary
(Note 5)
|
|
|
1,094
|
|
|
|
(76
|
)
|
|
|
2,182
|
|
|
|
(76
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other income (expense), net
|
|
|
933
|
|
|
|
(294
|
)
|
|
|
3,609
|
|
|
|
216
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) before income taxes and minority interest
|
|
|
16,401
|
|
|
|
2,055
|
|
|
|
38,664
|
|
|
|
(914
|
)
|
Income tax expense
|
|
|
(5,330
|
)
|
|
|
|
|
|
|
(14,117
|
)
|
|
|
|
|
Minority interest in net loss of subsidiary (Note 5)
|
|
|
7
|
|
|
|
455
|
|
|
|
58
|
|
|
|
391
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$
|
11,078
|
|
|
$
|
2,510
|
|
|
$
|
24,605
|
|
|
$
|
(523
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) per common share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$
|
0.15
|
|
|
$
|
0.04
|
|
|
$
|
0.35
|
|
|
$
|
(0.01
|
)
|
Diluted
|
|
|
0.15
|
|
|
|
0.04
|
|
|
|
0.35
|
|
|
|
(0.01
|
)
|
Weighted average shares outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
72,043
|
|
|
|
56,229
|
|
|
|
69,348
|
|
|
|
46,545
|
|
Diluted
|
|
|
72,908
|
|
|
|
59,989
|
|
|
|
70,274
|
|
|
|
46,545
|
|
See notes to condensed consolidated financial statements
4
Condensed
Consolidated Statements of Cash Flows
(Dollars
in thousands)
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
|
2007
|
|
|
2006
|
|
|
|
(Unaudited)
|
|
|
Cash Flows from Operating Activities
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$
|
24,605
|
|
|
$
|
(523
|
)
|
Adjustments to reconcile net income (loss) to net cash provided
by (used in) operating activities:
|
|
|
|
|
|
|
|
|
Depreciation
|
|
|
16,876
|
|
|
|
2,687
|
|
Amortization
|
|
|
1,292
|
|
|
|
824
|
|
Minority interest in net loss of subsidiary
|
|
|
(58
|
)
|
|
|
(391
|
)
|
Stock-based compensation expense
|
|
|
2,098
|
|
|
|
241
|
|
Deferred income taxes
|
|
|
14,252
|
|
|
|
812
|
|
Change in derivative financial instruments
|
|
|
4,880
|
|
|
|
(890
|
)
|
Equity in net (income) loss of unconsolidated subsidiary
|
|
|
(2,182
|
)
|
|
|
76
|
|
Loss on impairment of assets
|
|
|
2,471
|
|
|
|
|
|
Changes in working capital components, net of effects of
business acquisitions:
|
|
|
|
|
|
|
|
|
Receivables
|
|
|
(8,397
|
)
|
|
|
(16,714
|
)
|
Inventories
|
|
|
5,416
|
|
|
|
(6,522
|
)
|
Accounts payable
|
|
|
(4,567
|
)
|
|
|
13,741
|
|
Other, net
|
|
|
7,415
|
|
|
|
3,230
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in) operating activities
|
|
|
64,101
|
|
|
|
(3,429
|
)
|
|
|
|
|
|
|
|
|
|
Cash Flows from Investing Activities
|
|
|
|
|
|
|
|
|
Purchases of property and equipment
|
|
|
(287,193
|
)
|
|
|
(147,920
|
)
|
Proceeds from disposition of property and equipment
|
|
|
107
|
|
|
|
|
|
Acquisition of US Bio Marion, net of cash received
|
|
|
(13,224
|
)
|
|
|
|
|
Acquisition of US Bio Platte Valley and US Bio Ord, net of cash
received
|
|
|
|
|
|
|
(20,708
|
)
|
Investment in Provista
|
|
|
|
|
|
|
(1,000
|
)
|
Proceeds received on sale of 50 percent interest in Provista
|
|
|
|
|
|
|
2,400
|
|
Acquisition of US Bio Hankinson, LLC, net of cash received
|
|
|
|
|
|
|
(773
|
)
|
Deposits made
|
|
|
(2,660
|
)
|
|
|
(4,004
|
)
|
Other
|
|
|
|
|
|
|
157
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
(302,970
|
)
|
|
|
(171,848
|
)
|
|
|
|
|
|
|
|
|
|
Cash Flows from Financing Activities
|
|
|
|
|
|
|
|
|
Proceeds from long-term debt
|
|
|
210,844
|
|
|
|
99,485
|
|
Payments on long-term debt
|
|
|
(45,789
|
)
|
|
|
(1,645
|
)
|
Net change in notes payable
|
|
|
(1,815
|
)
|
|
|
12,451
|
|
(Decrease) increase in checks written on controlled disbursement
account
|
|
|
(13,270
|
)
|
|
|
1,066
|
|
Debt issuance costs paid
|
|
|
(1,542
|
)
|
|
|
(210
|
)
|
Proceeds from the issuance of 16,500 and 11,799,563 shares of
common stock, respectively
|
|
|
71
|
|
|
|
94,394
|
|
Deferred offering costs paid
|
|
|
|
|
|
|
(2,760
|
)
|
|
|
|
|
|
|
|
|
|
Net cash provided by financing activities
|
|
|
148,499
|
|
|
|
202,781
|
|
|
|
|
|
|
|
|
|
|
Net (decrease) increase in cash and cash equivalents
|
|
|
(90,370
|
)
|
|
|
27,504
|
|
Cash and Cash Equivalents
|
|
|
|
|
|
|
|
|
Beginning of period
|
|
|
170,099
|
|
|
|
40,450
|
|
|
|
|
|
|
|
|
|
|
End of period
|
|
$
|
79,729
|
|
|
$
|
67,954
|
|
|
|
|
|
|
|
|
|
|
See notes to condensed consolidated financial statements
5
US
BioEnergy Corporation
Notes
to Condensed Consolidated Financial Statements
(unaudited)
|
|
Note 1:
|
Basis of
Presentation and Significant Accounting Policies
|
The accompanying condensed consolidated financial statements
include the accounts of US BioEnergy Corporation (US BioEnergy
or USBE) and its wholly-owned subsidiaries, US Bio Albert City,
LLC (Albert City); US Bio Dyersville, LLC (Dyersville); US Bio
Hankinson, LLC (Hankinson); US Bio Janesville, LLC (Janesville);
US Bio Ord, LLC (Ord); US Bio Marion, LLC (Marion); US Bio
Platte Valley, LLC (Platte Valley); US Bio Woodbury, LLC
(Woodbury); UBE Services, LLC (UBE Services); United Bio Energy
Ingredients, LLC (UBE Ingredients) and its 50% joint ventures
Provista Renewable Fuels Marketing LLC, (Provista) and Big River
Resources Grinnell, LLC (Grinnell), all of which are
collectively referred to herein as the Company. All
material intercompany accounts and transactions have been
eliminated in consolidation.
The accompanying condensed consolidated balance sheet as of
December 31, 2006, which has been derived from the
Companys audited financial statements, and the unaudited
September 30, 2007 and 2006 condensed consolidated
financial statements have been prepared pursuant to the rules
and regulations of the Securities and Exchange Commission.
Certain information and note disclosures normally included in
the annual financial statements prepared in accordance with
generally accepted accounting principles have been condensed or
omitted pursuant to those rules and regulations. In the opinion
of management, the unaudited condensed consolidated financial
statements contain all normal recurring adjustments necessary
for a fair statement of the financial position and results of
operations and cash flows for the interim periods presented.
Management is required to make certain estimates and assumptions
which affect the amounts of assets, liabilities, revenues and
expenses the Company has recorded, and its disclosure of
contingent assets and liabilities at the date of the condensed
consolidated financial statements. The results of the interim
periods are not necessarily indicative of the results for the
full year. Accordingly, these condensed consolidated financial
statements should be read in conjunction with the audited
consolidated financial statements and the related notes included
in the Companys Annual Report on
Form 10-K
previously filed with the Securities and Exchange Commission as
of December 31, 2006.
On August 29, 2007, the Company acquired Millennium
Ethanol, LLC (Millennium), a development stage company, and
subsequently changed the name to US Bio Marion, LLC (Marion).
Marion is currently constructing an ethanol plant near Marion,
South Dakota. The Company has consolidated the activities of
Marion since the date of acquisition.
The Company accounts for its investment in Grinnell on a
consolidated basis, because it is a variable interest entity and
the Company is its primary beneficiary (see Note 5).
Beginning September 1, 2006, the Company has accounted for
its investment in Provista using the equity method of accounting
(see Note 5). Under this method, the Companys share
of the net income or loss of Provista is recognized in the
Companys statement of operations and added to or deducted
from investment in equity of unconsolidated subsidiary on the
Companys condensed consolidated balance sheet.
The company had the following change to its significant
accounting policies during the nine months ended
September 30, 2007:
Derivative financial
instruments:
During the first quarter of
2007, the Company began entering into exchange-traded energy
futures contracts to manage its risk on ethanol sales. During
the second quarter of 2007, the Company began entering into
over-the-counter financial instruments to manage its risk on
corn purchases. The Company accounts for these derivative
financial instruments at fair value in the financial statements
with changes in fair value being recorded in cost of goods sold.
Recently
issued accounting pronouncements:
In February 2007, the Financial Accounting Standards Board
(FASB) issued Statements of Financial Accounting Standards
(SFAS) No. 159, The Fair Value Option for Financial
Assets and Financial Liabilities
6
US
BioEnergy Corporation
Notes to
Condensed Consolidated Financial Statements
(unaudited) (Continued)
(SFAS No. 159) which included an amendment of
FASB Statement 115. This statement provides companies with an
option to report selected financial assets and liabilities at
fair value. This statement is effective for fiscal years
beginning after November 15, 2007, with early adoption
permitted. The Company is in the process of evaluating the
effect, if any, that the adoption of SFAS No. 159 will
have on its consolidated results of operations and financial
condition.
In September 2006, the FASB issued SFAS No. 157,
Fair Value Measurements
(SFAS No. 157) to increase consistency and
comparability in fair value measurements by defining fair value,
establishing a framework for measuring fair value in generally
accepted accounting principles, and expanding disclosures about
fair value measurements. SFAS No. 157 emphasizes that
fair value is a market-based measurement, not an entity-specific
measurement and is effective for the fiscal years beginning
after November 15, 2007. The Company is in the process of
evaluating the effect, if any, that the adoption of
SFAS No. 157 will have on its consolidated results of
operations and financial condition.
The Company adopted the provisions of FASB Interpretation (FIN)
No. 48 Accounting for Uncertainty in
Income Taxes an interpretation of
SFAS No. 109 (FIN 48), on January 1, 2007.
FIN 48 prescribes how a company should recognize, measure,
present and disclose uncertain tax positions that the Company
has taken or expects to take in its income tax returns.
FIN 48 requires that only income tax benefits that meet the
more likely than not recognition threshold be
recognized or continue to be recognized on its effective date.
As a result of the implementation of FIN 48, the Company
recognized a $0.2 million decrease in the liability for
unrecognized tax benefits. This decrease was accounted for as an
adjustment to the January 1, 2007, balance of retained
earnings.
The total gross amount of unrecognized tax benefits at
January 1, 2007, was approximately $1.3 million, of
which $0.7 million is reflected as long-term income taxes
payable and $0.6 million reduced the Companys
deferred tax asset related to net operating loss carryforwards.
As of January 1, 2007, if the total amount of unrecognized
tax benefits were recognized, the impact would not affect the
effective tax rate.
The Company recognizes interest and penalties accrued on
unrecognized tax benefits as well as interest received from
favorable tax settlements within income tax expense. The Company
did not accrue interest or penalties upon adoption of
FIN 48.
The Company files income tax returns in the U.S. federal
and several state jurisdictions. The Company is currently under
examination by the Internal Revenue Service for its 2005 and
2006 tax years. The Company has not recorded any material
adjustment in the liability for unrecognized income tax benefits
related to this audit. Additionally, the years 2004 through 2006
remain open for examination by federal and state authorities.
Gross unrecognized tax benefits increased in the third quarter
of 2007 by $3.4 million. Of this amount, $0.2 million,
if recognized, would have an impact on the effective tax rate.
Given that the Company is currently under audit by the IRS, it
is reasonably possible that significant changes in the gross
balance of unrecognized tax benefits may occur within the next
12 months. An estimate of the range of such gross changes
cannot be made at this time. However, the Company does not
expect the audit to result in amounts that would cause
significant change within the next twelve months to its
effective tax rate or expected cash payments for income taxes.
7
US
BioEnergy Corporation
Notes to
Condensed Consolidated Financial Statements
(unaudited) (Continued)
Inventories consist of the following
(in thousands)
:
|
|
|
|
|
|
|
|
|
|
|
September 30,
|
|
|
December 31,
|
|
|
|
2007
|
|
|
2006
|
|
|
Ethanol
|
|
$
|
4,454
|
|
|
$
|
4,752
|
|
Distillers grains
|
|
|
2,537
|
|
|
|
3,496
|
|
Corn
|
|
|
8,811
|
|
|
|
13,923
|
|
Chemicals
|
|
|
946
|
|
|
|
650
|
|
Supplies
|
|
|
3,376
|
|
|
|
2,095
|
|
Work-in-process
|
|
|
2,880
|
|
|
|
3,504
|
|
|
|
|
|
|
|
|
|
|
Inventories
|
|
$
|
23,004
|
|
|
$
|
28,420
|
|
|
|
|
|
|
|
|
|
|
|
|
Note 4:
|
Property
and Equipment
|
Property and equipment consist of the following
(in
thousands)
:
|
|
|
|
|
|
|
|
|
|
|
September 30,
|
|
|
December 31,
|
|
|
|
2007
|
|
|
2006
|
|
|
Land and land improvements
|
|
$
|
44,427
|
|
|
$
|
28,710
|
|
Buildings
|
|
|
92,278
|
|
|
|
74,080
|
|
Leasehold improvements
|
|
|
205
|
|
|
|
157
|
|
Machinery and equipment
|
|
|
270,896
|
|
|
|
224,232
|
|
Office furniture and equipment
|
|
|
5,236
|
|
|
|
2,359
|
|
Construction in progress
|
|
|
459,869
|
|
|
|
85,764
|
|
|
|
|
|
|
|
|
|
|
Property and equipment
|
|
|
872,911
|
|
|
|
415,302
|
|
Less: accumulated depreciation
|
|
|
23,181
|
|
|
|
6,488
|
|
|
|
|
|
|
|
|
|
|
Property and equipment, net
|
|
$
|
849,730
|
|
|
$
|
408,814
|
|
|
|
|
|
|
|
|
|
|
|
|
Note 5:
|
Investment
in Subsidiary
|
On February 1, 2007, the Company and Big River Resources,
LLC (Big River) entered into an agreement (Operating Agreement)
related to Grinnell. The Operating Agreement contained terms and
conditions related to the operation and governance of Grinnell,
an Iowa limited liability company formed for the purpose of
developing, constructing, owning, and operating an ethanol plant
near Grinnell, Iowa. The Company and Big River each own 50% of
Grinnell. In exchange for its 50% interest in Grinnell, the
Company contributed $4.0 million in cash and a build slot
under the master design-build agreement between the Company and
Fagen, Inc., dated August 10, 2006. Additional capital
contributions in connection with the construction of the plant
will be made as determined from time to time by the board of
Grinnell. The Company and Big River each have the right to
designate three managers to the board of managers of Grinnell.
Site work at the Grinnell plant commenced on December 1,
2006; however, due to lawsuits brought against Big River, and
certain other defendants, including the county zoning board,
related to zoning issues at the plant, no date has been set to
mobilize Fagen, Inc., the design-builder for the project, to
start the next phase of construction for the Grinnell plant. A
majority of the contested issues were favorably decided for Big
River on summary judgment, with Big River prevailing on the
remaining issues at trial in September 2007. However, the
plaintiff has requested a reconsideration of the decision, and
if the plaintiff is unsuccessful, the
8
US
BioEnergy Corporation
Notes to
Condensed Consolidated Financial Statements
(unaudited) (Continued)
Company believes that an appeal is likely. The Company has not
provided significant additional funding for the Grinnell plant,
since its original investment in February 2007.
The Company accounts for its investment in Grinnell on a
consolidated basis, because it is a variable interest entity and
the Company is its primary beneficiary.
In March 2006, the Company sold 50% of its membership interest
in its wholly-owned subsidiary, Provista, to CHS, Inc. (CHS), a
shareholder of the Company, for $2.4 million, plus the
assignment by CHS of a fuel delivery contract. UBE also assigned
certain of its fuel delivery contracts to Provista and agreed to
indemnify Provista for certain claims relating to
Provistas business prior to CHS becoming a member. The
Company refers to this arrangement as a joint venture with CHS.
A gain on the sale of $1.8 million was deferred until
December 2006.
The Company consolidated Provistas financial position and
results of operations through August 31, 2006, because
Provista was a variable interest entity and the Company was the
primary beneficiary. On August 31, 2006, the Companys
guarantee of Provistas debt was terminated and Provista
paid all outstanding indebtedness to the Company, except for
trade receivables related to ongoing business transactions.
Beginning September 1, 2006, the Company has accounted for
its investment in Provista as an unconsolidated subsidiary under
the equity method of accounting. Total net revenues for Provista
which represent the period beginning January 1, 2006 and
ending August 31, 2006, as reflected in the statements of
operations were $3.8 million.
|
|
Note 6:
|
Notes
Payable and Long-Term Debt
|
On February 7, 2007, the Company entered into five senior
secured credit facilities with AgStar Financial Services, PCA,
(AgStar) as administrative agent and as a lender, and a group of
other lenders. The senior secured credit facilities include
$337.0 million structured as construction loans for
Hankinson, Janesville, Dyersville and Ord and $90.0 million
for Platte Valley to refinance its existing credit facility. The
construction loan includes up to $5.0 million per project
to be available for letters of credit. The Hankinson, Janesville
and Dyersville construction loans will provide funds necessary
to finance up to 60% of construction costs. The Company must
provide the necessary funds for 40% of the construction costs
before funds are available under each credit facility. In
addition, a $10.0 million seasonal revolving credit
facility is available under the senior secured credit facility
for the Platte Valley and Ord plants and a $10.0 million
seasonal revolving credit facility will be available to each of
Hankinson, Janesville and Dyersville upon the conversion of each
construction loan to a term loan. On February 7, 2007, the
Company used funds from the new credit facilities to prepay all
the outstanding debt with First National Bank of Omaha in
aggregate of $36.8 million. In connection with the
refinancing the Company incurred and expensed a prepayment
penalty of $0.7 million and $0.7 million of debt
financing costs.
As of September 30, 2007, the Company held the following
positions:
Albert City had outstanding borrowings of $64.6 million and
$12.6 million under its senior secured credit facility and
revolving term loan, respectively, and outstanding letters of
credit of $2.7 million. There were no outstanding
borrowings under its seasonal revolving loan.
Ord had outstanding borrowings of $34.9 million and
$11.6 million under its senior secured credit facility and
revolving term loan, respectively. There were no outstanding
borrowings under its seasonal revolving loan. Ords
construction loan converted to term loans on September 1,
2007.
Platte Valley had outstanding borrowings of $65.9 million
and $22.5 million under its senior secured credit facility
and revolving term loan, respectively, and outstanding letters
of credit of $0.5 million. There were no outstanding
borrowings under its seasonal revolving loan.
Woodbury had outstanding borrowings of $27.0 million and
$8.0 million under its senior secured credit facility and
revolving term loan, respectively, and outstanding letters of
credit of $0.9 million.
9
US
BioEnergy Corporation
Notes to
Condensed Consolidated Financial Statements
(unaudited) (Continued)
Dyersville had outstanding borrowings under its construction
loan of $8.9 million and no outstanding letters of credit.
Hankinson had outstanding borrowings under its construction loan
of $34.7 million and outstanding letters of credit of
$4.3 million.
Janesville had no outstanding borrowings under its construction
loan and no outstanding letters of credit.
Marion had outstanding borrowings under its construction loan of
$51.9 million, no amounts outstanding on its revolving
credit facility and outstanding letters of credit of
$1.1 million. On August 29, 2007, the Company acquired
Millennium, a development stage company, which it subsequently
named US Bio Marion, LLC (Marion). Marion is constructing an
ethanol plant near Marion, South Dakota (see Note 9 for
more detail). The senior construction loan, with Dougherty
Funding LLC (Dougherty), has a total commitment of
$90.0 million, which bears interest at 4.5% above the
one-month LIBOR and a revolving loan of up to $7.0 million,
which bears interest at 4% above the one-month LIBOR. During the
construction phase, interest on the senior construction loan is
due monthly. The term of the senior construction loan commitment
allows advances to be made through May 31, 2008. After
conversion of the senior construction loan to a term loan,
payments will be based on monthly amortized payments of
principal and interest sufficient to amortize the remaining
unpaid principal balance to a maturity date of March 31,
2013. The senior construction loan is secured by substantially
all of the assets of Marion. The revolving line of credit is
secured by Marions inventory and accounts receivable and
expires on May 28, 2009. Marion also has availability of
$7.3 million under a letters of credit agreement with First
Bank & Trust, a South Dakota state bank, to be issued
on behalf of Marion to satisfy the requirements of certain
utility service providers to secure Marions contractual
obligation to them under certain agreements with these service
utility providers.
|
|
Note 7:
|
Earnings
Per Common Share
|
On December 8, 2006, the Companys shareholders
approved a
1-for-4
reverse stock split of the Companys common stock, which
became effective on December 12, 2006. The par value of
common shares remained $0.01 per share. The reverse stock split
has been retroactively reflected in these condensed consolidated
financial statements for all periods presented.
10
US
BioEnergy Corporation
Notes to
Condensed Consolidated Financial Statements
(unaudited) (Continued)
A reconciliation of net income (loss) and common stock share
amounts used in the calculation of basic and diluted earnings or
loss per share (EPS) for the three and nine months ended
September 30, 2007 and 2006, are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30,
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
|
Average
|
|
|
|
|
|
|
Net
|
|
|
Shares
|
|
|
Per Share
|
|
|
|
Income
|
|
|
Outstanding
|
|
|
Amount
|
|
|
|
(In thousands)
|
|
|
|
|
|
|
|
|
2007:
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic EPS
|
|
$
|
11,078
|
|
|
|
72,042,778
|
|
|
$
|
0.15
|
|
Effects of dilutive securities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Exercise of stock options
|
|
|
|
|
|
|
865,337
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted EPS
|
|
$
|
11,078
|
|
|
|
72,908,115
|
|
|
$
|
0.15
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2006:
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic EPS
|
|
$
|
2,510
|
|
|
|
56,229,063
|
|
|
$
|
0.04
|
|
Effects of dilutive securities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Exercise of stock options
|
|
|
|
|
|
|
3,759,550
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted EPS
|
|
$
|
2,510
|
|
|
|
59,988,613
|
|
|
$
|
0.04
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30,
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
|
Average
|
|
|
|
|
|
|
Net
|
|
|
Shares
|
|
|
Per Share
|
|
|
|
Income (Loss)
|
|
|
Outstanding
|
|
|
Amount
|
|
|
|
(In thousands)
|
|
|
|
|
|
|
|
|
2007:
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic EPS
|
|
$
|
24,605
|
|
|
|
69,347,828
|
|
|
$
|
0.35
|
|
Effects of dilutive securities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Exercise of stock options
|
|
|
|
|
|
|
926,151
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted EPS
|
|
$
|
24,605
|
|
|
|
70,273,979
|
|
|
$
|
0.35
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2006:
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic EPS
|
|
$
|
(523
|
)
|
|
|
46,545,141
|
|
|
$
|
(0.01
|
)
|
Effects of dilutive securities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Exercise of stock options
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted EPS
|
|
$
|
(523
|
)
|
|
|
46,545,141
|
|
|
$
|
(0.01
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Options outstanding of 480,375 and 1,971,250 in 2007 and 2006,
respectively, were not included in the computation of diluted
EPS because their effect would have been antidilutive. All
restricted stock has been included in the computation of diluted
EPS. There was no restricted stock outstanding for the three and
nine months ended September 30, 2006.
|
|
Note 8:
|
Stock-Based
Compensation and Payments
|
Effective January 1, 2006, the Company adopted
SFAS No. 123 (Revised 2004), Share-Based
Payment, (SFAS 123(R)), which requires the
measurement and recognition of compensation cost at fair value
for all
11
US
BioEnergy Corporation
Notes to
Condensed Consolidated Financial Statements
(unaudited) (Continued)
share-based payments made to employees and directors, including
stock options and employee stock purchases related to the
Employee Stock Purchase Plan (ESP Plan).
The Company adopted SFAS 123(R) using the prospective
transition method, which requires the application of the
accounting standard as of January 1, 2006. The condensed
consolidated financial statements for the three and nine months
ended September 30, 2006, reflect the impact of
SFAS 123(R).
For the three months ended September 30, 2007, total
compensation recognized in the statement of operations for all
stock based compensation arrangements was $0.7 million,
with a recognized deferred income tax benefit of
$0.2 million. For the same three months ended
September 30, 2006, total compensation expense recognized
in the statement of operations for all stock based compensation
arrangements was $0.2 million, with a deferred income tax
expense of $49,000 related thereto.
For the nine months ended September 30, 2007 and 2006,
respectively, the Company recognized expenses of
$2.1 million and $0.2 million in the statement of
operations for all stock-based compensation arrangements, and
recognized related deferred income tax benefits of
$0.6 million and $50,000, respectively.
Stock Incentive Plans
:
The US BioEnergy
Corporation 2005 Stock Incentive Plan (2005 Plan) was
administered by the Board of Directors or, at its discretion, by
a committee consisting of at least three members of the Board of
Directors. The 2005 Plan permitted the grant of awards in the
form of options, which could have been incentive stock options
or non-qualified stock options, stock appreciation rights,
restricted stock, or deferred stock. The Board of Directors
could award unrestricted awards to recipients in its discretion
or upon the attainment of specified performance goals. A total
of 426,750 shares were awarded under the 2005 incentive
plan. As of September 30, 2007, 241,250 shares were
still outstanding under this Plan. The 2005 stock incentive plan
was superseded by the 2006 stock incentive plan.
On December 8, 2006 the Companys shareholders
approved the US BioEnergy Corporation 2006 Stock Incentive Plan
(2006 Plan). The 2006 Plan is administered by the Board of
Directors or, at its discretion, by a committee consisting of at
least two members of the Board of Directors. The 2006 Plan
permits the grant of awards in the form of options, which may be
incentive stock options or non-qualified stock options, stock
appreciation rights, restricted stock, or deferred stock. The
Board of Directors may award unrestricted awards to recipients
at its discretion or upon the attainment of specified
performance goals.
The maximum number of shares reserved under the Plan is
6,560,943 shares of Class A common stock (Award
Shares). Award Shares covered by expired or terminated stock
options and forfeited shares of restricted stock or deferred
stock may be used for subsequent awards under the Plan. The
Company has the ability to settle equity awards through the
issuance of authorized but unissued common stock. As of
September 30, 2007, there were 5,957,045 shares
available to be awarded under the 2006 Plan. No awards shall be
granted under the 2006 Plan more than ten years after the date
of adoption of the 2006 Plan.
Restricted stock
:
In December 2006, the
Company awarded 223,952 shares of restricted stock to
certain employees and 19,250 shares of restricted stock to
certain members of the Companys Board of Directors under
the 2006 Plan. The restricted stock granted to employees
generally vests ratably over three to five years, based on the
grant, as long as the employees are employed by the Company. The
restricted stock granted to the members of the Companys
Board of Directors in December 2006 vested on May 30, 2007,
the date immediately prior to the Companys 2007 annual
shareholders meeting. In April 2007, the Company awarded
24,240 shares of restricted stock to certain members of the
Companys local advisory boards and 21,612 shares of
restricted stock to the Companys Board of Directors under
the 2006 Plan. On August 21, 2007, the Company awarded
338,707 shares of restricted stock to all employees under
the 2006 Plan. The Company had historically applied an average
annual forfeiture rate of 2% when calculating the number of
shares expected to vest, based upon comparable information for
similar businesses. During the second quarter of 2007, the
Company did a re-evaluation of the forfeiture rate and will be
applying a new rate of 15% on future grants, except grants to
board members, which do not have a forfeiture rate. Unrecognized
compensation expense
12
US
BioEnergy Corporation
Notes to
Condensed Consolidated Financial Statements
(unaudited) (Continued)
related to the restricted stock grants was approximately
$6.0 million at September 30, 2007, which is expected
to be recognized over a weighted average period of
2.6 years. A summary of nonvested shares for the nine
months ended September 30, 2007, is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted-
|
|
|
|
Number of
|
|
|
Average
|
|
|
|
Nonvested
|
|
|
Grant Date
|
|
|
|
Shares
|
|
|
Fair Value
|
|
|
Outstanding on December 31, 2006
|
|
|
239,452
|
|
|
$
|
14.00
|
|
Granted
|
|
|
384,559
|
|
|
$
|
11.07
|
|
Vested
|
|
|
(46,414
|
)
|
|
$
|
14.03
|
|
Forfeited
|
|
|
(37,837
|
)
|
|
$
|
13.99
|
|
|
|
|
|
|
|
|
|
|
Outstanding on September 30, 2007
|
|
|
539,760
|
|
|
$
|
11.91
|
|
|
|
|
|
|
|
|
|
|
Stock options
:
Stock options under the
2005 and 2006 Plans (Plans) are subject to a vesting period of
up to five years from the date of grant. Compensation expense is
recognized on a straight-line basis over the vesting period. The
term of an incentive stock option may not exceed ten years (or
five years if issued to an optionee who owns or is deemed to own
more than 10% of the combined voting power of all classes of the
Companys stock, a subsidiary, or any affiliate). The
exercise price of a stock option may not be less than the fair
market value of the stock on the date the option is granted or,
in the event the optionee owns more than 10% of the combined
voting power of all classes of capital stock of the Company and
an incentive stock option is granted to such optionee, the
option exercise price shall not be less than 110% of the fair
market value of the stock on the date the option is granted.
In addition to the options granted under the Plans, the Company
has 1,625,000 options outstanding which were granted outside of
the Companys 2005 Plan.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
|
Average
|
|
|
Average
|
|
|
Aggregate
|
|
|
|
Number of
|
|
|
Exercise
|
|
|
Remaining
|
|
|
Intrinsic
|
|
|
|
Stock
|
|
|
Price
|
|
|
Contractual
|
|
|
Value
|
|
|
|
Options
|
|
|
per Share
|
|
|
Term (in Years)
|
|
|
(In thousands)
|
|
|
Outstanding on December 31, 2006
|
|
|
2,505,750
|
|
|
$
|
6.42
|
|
|
|
|
|
|
|
|
|
Granted
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Exercised
|
|
|
(16,500
|
)
|
|
|
4.30
|
|
|
|
|
|
|
|
|
|
Forfeited
|
|
|
(170,950
|
)
|
|
|
11.73
|
|
|
|
|
|
|
|
|
|
Expired
|
|
|
(8,300
|
)
|
|
|
4.24
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding on September 30, 2007
|
|
|
2,310,000
|
|
|
$
|
6.05
|
|
|
|
8.34
|
|
|
$
|
6,782
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Exercisable at September 30, 2007
|
|
|
1,721,200
|
|
|
$
|
4.04
|
|
|
|
8.13
|
|
|
$
|
6,355
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As of September 30, 2007, there was $3.3 million of
unrecognized compensation expense related to nonvested stock
options. This amount is expected to be recognized as
compensation expense over a weighted average period of
4.1 years.
There were no options granted during the three months ended
September 30, 2006, and as a result, there was no
calculation of a weighted average grant fair date for that
period. During the three months ended September 30, 2007,
5,750 options, which had an intrinsic value of $39,000, were
exercised for cash proceeds of $23,000. The exercise of the
stock options resulted in a tax benefit of $4,000 for the
Company. The Company issued new shares to satisfy these
exercises. No options were exercised during the three months
ended September 30, 2006. The Company expects to satisfy
exercises of options in the future through the issuance of
authorized but unissued common stock.
13
US
BioEnergy Corporation
Notes to
Condensed Consolidated Financial Statements
(unaudited) (Continued)
The weighted average grant date fair value of stock options
granted during the nine months ended September 30, 2006 was
$7.92. During the nine months ended September 30, 2007,
16,500 options, which had an intrinsic value of $141,000, were
exercised for cash proceeds of $71,000. The exercise of the
stock options resulted in a tax benefit of $28,000 for the
Company. The Company issued new shares to satisfy these
exercises. No options were exercised during the nine months
ended September 30, 2006. The Company expects to satisfy
exercises of options in the future through the issuance of
authorized but unissued common stock.
The Company uses the Black-Scholes option pricing model to
estimate the fair value of stock option awards. The Company had
historically applied an annual forfeiture rate of 2% when
calculating the amount of options to vest. This rate was based
on comparable information for similar businesses. During the
second quarter of 2007, the Company did a re-evaluation of the
forfeiture rate, and will be applying a new rate of 15% on
future grants except grants to board members, which do not have
a forfeiture rate. The expected term assumption used in the
option pricing model was based on the safe harbor
approach under SEC Staff Accounting Bulletin
(SAB) No. 107, (SAB 107), where the expected
term = ((vesting term + original contractual
term) / 2). The expected stock price volatility
assumption was based on the average volatility of a similar
public company for the period prior to the Companys
initial public offering. The risk free interest rate assumption
was based on the implied yield currently available on
U.S. Treasury zero coupon issues with remaining term equal
to the expected term. A projected dividend yield of 0% was used
as the company has never issued dividends.
Employee Stock Purchase Plan:
On
December 8, 2006, the Companys shareholders approved
the 2006 ESP Plan. The ESP Plan provides eligible employees an
opportunity to purchase shares of the Companys common
stock through payroll deductions of up to 10 percent of
eligible compensation. The plan provides for two six-month
purchase periods per year, beginning December 1 and June 1,
which are the grant dates. On May 31 and November 30, the
exercise dates, participant account balances are used to
purchase shares of stock at 90 percent of the closing price
of the shares on the lesser of the grant date or the exercise
date. The ESP Plan expires September 20, 2016. A maximum of
3,280,472 shares are available for purchase under the ESP
Plan. Stock sales under the ESP Plan result in the recognition
of compensation expense, which equals the discount to the
closing price on the date of purchase. There have been no
purchases under the plan as of September 30, 2007. The
first purchase date will be December 1, 2007.
Amendments to Stock Option
Agreements:
On June 23, 2006 the Company
modified two option grants. The grants were to two individuals
who were members of the Board of Directors as of the original
grant date. Under the terms of the original grant, if the
individuals no longer served on the Board of Directors, the
options were to terminate. On June 23, 2006, these
individuals ceased to be members of the Board, however, the
Company agreed to allow the options to continue in effect in
exchange for the individuals providing consulting services to
the Company over the remaining vesting period. A total of 30,000
options were affected by this modification. Additional
compensation expense of approximately $0.1 million was
recognized related to this modification. Additional unrecognized
compensation expense of approximately $0.1 million is
expected to be recognized over the next 13 months as a
result of the modifications.
On November 10, 2005, the Financial Accounting Standards
Board (FASB) issued FASB Staff Position No. 123(R)-3,
Transition Election Related to Accounting for Tax Effects
of Share-Based Payment Awards (FSP
No. FAS 123(R)-3). FSP No. 123(R)-3 provides an
alternative method of calculating the excess tax benefits
available to absorb tax deficiencies recognized after the
adoption of SFAS 123(R). The calculation of excess tax
benefits recorded as an operating cash outflow and a financing
inflow in the condensed consolidated Statements of Cash Flows
required by FSP No. FAS 123(R)-3 differs from that
required by SFAS 123(R). The Company has until December
2007 to make a one-time election to adopt the transition method
described in FSP No. FAS 123(R)-3. The Company is
currently evaluating FSP No. FAS 123(R)-3; however,
the one-time election will not affect operating income or net
income. During the interim period, the Company used the
14
US
BioEnergy Corporation
Notes to
Condensed Consolidated Financial Statements
(unaudited) (Continued)
alternative method of calculating the excess tax benefits
available to absorb tax deficiencies recognized after the
adoption of SFAS 123(R).
On March 31, 2006, the Company acquired all the outstanding
common shares of Hankinson, a development stage company. The
operations of Hankinson were included in the Companys
condensed consolidated financial statements beginning
April 1, 2006. Hankinson was formed in 2005 to develop,
construct, own and operate an ethanol plant near Hankinson,
North Dakota. The Company commenced construction at Hankinson in
the third quarter of 2006.
On April 30, 2006, the Company acquired all of the
outstanding common shares of Platte Valley and Ord. The results
of their operations have been included in the condensed
consolidated financial statements beginning May 1, 2006. At
the time of acquisition, Platte Valley was operating as a 50
mmgy ethanol plant near Central City, Nebraska. In November
2006, the Company completed an expansion project at its Platte
Valley plant, which resulted in total production capacity of 100
mmgy. At the time of acquisition Ord was a development stage
company, formed in 2005 to develop, construct, own and operate
an ethanol plant near Ord, Nebraska. Ord began production in May
of 2007.
Marion
Acquisition:
On May 31, 2007, the Company, and Millennium Ethanol, LLC,
a South Dakota limited liability company, entered into an
Agreement and Plan of Merger, which provided for the acquisition
of Millennium by the Company. On August 29, 2007, the
Company completed the acquisition of Millennium for total
aggregate net consideration of $130.9 million, which was
comprised of 11,292,168 shares of US BioEnergy Common
Stock, and $11.6 million of cash. The Company also incurred
transaction costs of $1.7 million. The total purchase
price, including transaction costs, was $132.6 million.
Millennium was a development stage company that was in the
process of constructing an ethanol plant near Marion, South
Dakota. The Company changed the name to US Bio Marion, LLC
(Marion) upon completion of the acquisition. The Company
believes that this acquisition will increase its total
production capacity once construction is completed and
commercial operations begin. The operations of Marion were
included in the condensed consolidated financial statements
beginning on August 29, 2007.
The total purchase price was comprised of (in thousands):
|
|
|
|
|
Value of common stock issued in exchange for shares in
Millennium:
|
|
|
|
|
11,292,168 shares at $10.57 per share
|
|
$
|
119,358
|
|
Cash paid
|
|
|
11,564
|
|
|
|
|
|
|
Total consideration
|
|
$
|
130,922
|
|
Transaction costs
|
|
|
1,680
|
|
|
|
|
|
|
Total purchase price
|
|
$
|
132,602
|
|
|
|
|
|
|
Intangible assets consist of debt financing costs related to the
construction term loan. Property and equipment acquired
consisted primarily of the values assigned to the construction
that was in progress at the time of acquisition and the value
assigned to the contract to build the ethanol plant, which will
be depreciated over the estimated useful lives, which range from
3 to 40 years, of the related assets once operations
commence.
The purchase price was allocated to the assets acquired based
upon their estimated relative fair values. The Company has
estimated the fair values of the acquired assets based on a
number of factors, including third-party valuations and its own
assumptions, which are subject to change once the Company has
completed
15
US
BioEnergy Corporation
Notes to
Condensed Consolidated Financial Statements
(unaudited) (Continued)
the fair value allocations. The following table summarizes the
preliminary allocations to the assets acquired at the date of
the Marion acquisition
(in thousands)
:
|
|
|
|
|
Cash and cash equivalents
|
|
$
|
20
|
|
Current assets
|
|
|
314
|
|
Property and equipment, net
|
|
|
166,071
|
|
Intangible assets
|
|
|
3,254
|
|
|
|
|
|
|
Total assets acquired
|
|
|
169,659
|
|
Accounts payable
|
|
|
(3,286
|
)
|
Accrued expenses
|
|
|
(22
|
)
|
Long-term debt
|
|
|
(33,749
|
)
|
|
|
|
|
|
Total liabilities assumed
|
|
|
(37,057
|
)
|
|
|
|
|
|
Net assets acquired
|
|
$
|
132,602
|
|
|
|
|
|
|
Unaudited pro forma consolidated results of operations for the
three and nine months ended September 30, 2007 and 2006, as
though Hankinson, Platte Valley, Ord and Marion had been
acquired as of the beginning of 2006 are as follows
(in
thousands, except per share data):
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
|
Nine Months
|
|
|
|
Ended
|
|
|
Ended
|
|
|
|
September 30,
|
|
|
September 30,
|
|
|
|
2007
|
|
|
2007
|
|
|
Total revenues
|
|
$
|
150,045
|
|
|
$
|
436,666
|
|
Net income
|
|
|
11,013
|
|
|
|
23,232
|
|
Net income per share-basic
|
|
|
0.15
|
|
|
|
0.34
|
|
Net income per share-diluted
|
|
|
0.15
|
|
|
|
0.33
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
|
Nine Months
|
|
|
|
Ended
|
|
|
Ended
|
|
|
|
September 30,
|
|
|
September 30,
|
|
|
|
2006
|
|
|
2006
|
|
|
Total revenues
|
|
$
|
33,657
|
|
|
$
|
93,398
|
|
Net income
|
|
|
1,149
|
|
|
|
4,286
|
|
Net income per share-basic
|
|
|
0.02
|
|
|
|
0.07
|
|
Net income per share-diluted
|
|
|
0.02
|
|
|
|
0.07
|
|
|
|
Note 10:
|
Condensed
Segment Information
|
The Companys Production segment includes those production
plants that are currently producing ethanol or are being
constructed for that purpose. The Production segment includes
the activities of Albert City, Ord, Platte Valley, Woodbury,
Hankinson, Dyersville, Janesville, Marion and Grinnell. The All
Other category in the following tables is primarily the
marketing and management operations of UBE Services, UBE
Ingredients and Provista, cash to be used towards the
construction of ethanol plants, intersegment receivables and
corporate operations. Beginning September 1, 2006, the
activities of Provista have been accounted for under the equity
method of accounting and, as such, the assets in the All Other
segment category no longer include the assets of Provista,
except for the Companys equity method investment in
Provista. All Other includes the
16
US
BioEnergy Corporation
Notes to
Condensed Consolidated Financial Statements
(unaudited) (Continued)
statement of operations information for Provista on a
consolidated basis for the period beginning January 1,
2006, and ending August 31, 2006. A summary of segment
information is as follows
(in thousands)
:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30, 2007
|
|
|
|
Production
|
|
|
All Other
|
|
|
Total
|
|
|
Revenues from external customers
|
|
$
|
147,406
|
|
|
$
|
2,639
|
|
|
$
|
150,045
|
|
Intersegment revenues
|
|
|
|
|
|
|
430
|
|
|
|
430
|
|
Segment income (loss) before taxes and minority interest
|
|
|
20,166
|
|
|
|
(3,765
|
)
|
|
|
16,401
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30, 2006
|
|
|
|
Production
|
|
|
All Other
|
|
|
Total
|
|
|
Revenues from external customers
|
|
$
|
31,584
|
|
|
$
|
1,666
|
|
|
$
|
33,250
|
|
Intersegment revenues
|
|
|
|
|
|
|
156
|
|
|
|
156
|
|
Segment income (loss) before taxes and minority interest
|
|
|
7,062
|
|
|
|
(5,007
|
)
|
|
|
2,055
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30, 2007
|
|
|
|
Production
|
|
|
All Other
|
|
|
Total
|
|
|
Revenues from external customers
|
|
$
|
427,384
|
|
|
$
|
9,282
|
|
|
$
|
436,666
|
|
Intersegment revenues
|
|
|
|
|
|
|
1,271
|
|
|
|
1,271
|
|
Segment income (loss) before taxes and minority interest
|
|
|
41,477
|
|
|
|
(2,813
|
)
|
|
|
38,664
|
|
Segment assets as of September 30, 2007
|
|
|
1,025,621
|
|
|
|
63,712
|
|
|
|
1,089,333
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30, 2006
|
|
|
|
Production
|
|
|
All Other
|
|
|
Total
|
|
|
Revenues from external customers
|
|
$
|
48,319
|
|
|
$
|
12,045
|
|
|
$
|
60,364
|
|
Intersegment revenues
|
|
|
|
|
|
|
316
|
|
|
|
316
|
|
Segment income (loss) before taxes and minority interest
|
|
|
11,044
|
|
|
|
(11,958
|
)
|
|
|
(914
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Segment assets as of December 31, 2006
|
|
|
537,395
|
|
|
|
196,395
|
|
|
|
733,790
|
|
Revenue is recognized when the title transfers to the customer.
Ethanol is generally shipped FOB shipping point. For the period
beginning January 1, 2006 and ending August 31, 2006,
the Company recorded the activities of Provista on a
consolidated basis. During this time period the Companys
customers were the customers of Provista; principally refining
and marketing companies who blend ethanol with gasoline. On
August 31, 2006, the Company discontinued consolidating
Provista, because the Company was no longer the primary
beneficiary, and began accounting for its investment in Provista
under the equity method of accounting. At that time the
Companys customer became Provista, its marketing joint
venture. Since August 31, 2006, 100% of the Companys
ethanol sales have been to Provista, which, in turn, resells the
ethanol to the refining and marketing companies.
For the three and nine months ended September 30, 2007, the
Company recorded net sales of $129.0 million and
$371.4 million, respectively, to Provista, which
represented over 10% of total revenues for this period. The
sales to Provista represent 100% of the Companys ethanol
sales, and were recorded within the Production segment.
For the period beginning January 1, 2006, to the period
ending August 31, 2006, the Company recorded net sales of
$7.9 million to Valero, and $6.2 million to Elbow
River. For the period beginning September 1, 2006 and ended
September 30, 2006, the Company recorded net sales of
$10.2 million to Provista. These three customers
represented over 10% of the total revenues for the nine months
ended September 30, 2006.
17
US
BioEnergy Corporation
Notes to
Condensed Consolidated Financial Statements
(unaudited) (Continued)
|
|
Note 11:
|
Commitments
and Contingencies
|
As of September 30, 2007, the Company had commitments to
Fagen Inc., an entity controlled by Roland (Ron) Fagen, one of
the Companys largest shareholders, of approximately
$176.0 million. These commitments are in connection with
the Companys ethanol construction projects currently
underway at Hankinson, North Dakota, Dyersville, Iowa,
Janesville, Minnesota and Marion, South Dakota.
|
|
Note 12:
|
Goodwill
and Intangible Assets
|
Goodwill and intangible assets are reviewed for impairment
annually in the fourth quarter or more frequently if certain
impairment conditions arise. In September 2007, the Company
determined that based on discounted estimated future cash flows,
the carrying amount of the goodwill and intangible assets, which
were assigned to UBE, its marketing and services business in the
All Other segment category, exceeded its fair value in aggregate
by $2.5 million. The aggregate amount of $2.5 million
consisted of a goodwill impairment of $1.8 million and
intangible assets, which consisted of customer lists and
contracts, of $0.7 million. Accordingly, an impairment loss
of $2.5 million was recognized and is reported as a loss on
impairment of assets in the consolidated statements of
operations.
Note 13: Subsequent
Event
On November 2, 2007, the Company entered into a Second
Amended and Restated Guaranty, the terms of which provide that
the Company will guarantee up to the lesser of 50% or
$10.0 million of Provistas debt outstanding pursuant
to the Amended and Restated Loan and Security Agreement dated as
of August 31, 2006, between Provista and LaSalle Bank
National Association, as subsequently amended. Prior to the
execution of the guaranty by the Company, CHS, Inc. had
guaranteed up to $20.0 million of Provistas indebtedness
under the loan agreement. Following the execution of the
guaranty, CHS, Incs. guarantee was reduced to
$10.0 million by the execution of a Guarantee substantially
similar to that executed by the Company.
The Company is currently evaluating whether the execution of
this agreement will require the Company to begin consolidating
Provista again. If the Company determines that it will continue
to account for Provista using the equity method of accounting,
it will treat the guaranty as an off-balance sheet arrangement,
and will report it as such.
18
|
|
ITEM 2.
|
MANAGEMENTS
DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
|
The following discussion should be read in conjunction with the
unaudited condensed consolidated financial statements and the
notes included in Item 1 of Part I of this Quarterly
Report and the audited consolidated financial statements and
notes, and Managements Discussion and Analysis of
Financial Condition and Results of Operations, contained in the
Companys Annual Report on
Form 10-K
for the fiscal year ended December 31, 2006. The following
discussion contains forward-looking statements that reflect our
plans, estimates and beliefs. Our actual results could differ
materially from those discussed in the forward-looking
statements. Factors that could cause or contribute to these
differences include those discussed or referred to below under
Cautionary Statement for Purposes of the Safe Harbor
Provisions of the Private Securities Litigation Reform Act of
1995.
GENERAL
We are one of the largest producers of ethanol in the United
States. We own and operate four ethanol plants with total
ethanol production capacity of 310 million gallons per year
(mmgy) and are constructing four additional ethanol plants with
expected total ethanol production capacity of 440 mmgy. We are
also implementing US Bio Process
Technology
tm
,
our proprietary process improvement initiatives, which are
designed to achieve increased production levels at our plants.
We believe these improvements will position us to achieve total
ethanol production capacity of 800 mmgy once fully implemented
at each of our plants.
Our primary products are ethanol and distillers grains, which we
derive from corn. We sell our ethanol to Provista Renewable
Fuels Marketing LLC (Provista), our ethanol marketing joint
venture with CHS, Inc., which in turn resells to refining and
marketing companies, such as BP North America, Inc., Chevron
Texaco Products Company and Marathon Petroleum Company, LLC. We
believe that Provistas customers blend ethanol with
gasoline in order to capture attractive economics relative to
refining costs, to achieve higher octane levels for their
products, to facilitate compliance with clean air regulations
and to extend their processing capacities. We sell our
distillers grains to livestock operators and marketing companies
in the U.S. and internationally primarily to be used as an
animal feed. We also market distillers grains for, and provide
facilities management and other services to other ethanol
producers.
Previously, we have referred to nameplate capacity
of our operational plants as well as those under construction.
As we continue to develop operational experience and implement
US Bio Process
Technology
tm
,
we have determined that it is more meaningful to refer to our
plants by their expected capacity. Accordingly, instead of
referring to nameplate capacity of our plants, we
will now refer to Ord and Woodbury as 50 mmgy plants, we will
refer to our expanded Platte Valley plant as a 100 mmgy plant,
and we will refer to Albert City, Marion, Hankinson, Dyersville
and Janesville as 110 mmgy plants. We believe that this better
reflects our expectations and is in accord with industry
practice.
The following table sets forth a summary of our ethanol plants
that are currently in operations or under construction as of
September 30, 2007:
|
|
|
|
|
|
|
|
|
|
|
|
|
In Operation
|
|
|
Albert City
|
|
Ord
|
|
Platte Valley
|
|
Woodbury
|
|
Total
|
|
Location
|
|
Albert City,
Iowa
|
|
Ord,
Nebraska
|
|
Central City,
Nebraska
|
|
Lake Odessa,
Michigan
|
|
|
Commercial operation date
|
|
December
2006
|
|
May
2007
|
|
May
2004
(1)
|
|
September
2006
|
|
|
Current ethanol production capacity (mmgy)
|
|
110
|
|
50
|
|
100
|
|
50
|
|
310
|
19
|
|
|
|
|
|
|
|
|
|
|
|
|
Under Construction
|
|
|
Marion
|
|
Hankinson
|
|
Dyersville
|
|
Janseville
|
|
Total
|
|
Location
|
|
Marion,
South Dakota
|
|
Hankinson,
North Dakota
|
|
Dyersville,
Iowa
|
|
Janesville,
Minnesota
|
|
|
Expected ethanol production capacity (mmgy)
|
|
110
|
|
110
|
|
110
|
|
110
|
|
440
|
Construction start date
|
|
Q3 2006
|
|
Q3 2006
|
|
Q4 2006
|
|
Q1 2007
|
|
|
Estimated production start date
|
|
Q1 2008
|
|
Q2 2008
|
|
Q2 2008
|
|
Q3 2008
|
|
|
|
|
|
(1)
|
|
Platte Valley began commercial operations of a 50 mmgy plant in
May 2004. We acquired Platte Valley in April 2006 and expanded
the plant to 100 mmgy in November 2006.
|
We also have a 50% interest in a joint venture organized to
construct, own and operate an ethanol plant that is located near
Grinnell, Iowa, with the other 50% interest being held by Big
River Resources, LLC (Big River). Site work at the Grinnell
plant commenced on December 1, 2006; however, due to
pending lawsuits brought against Big River, and certain other
defendants, including the county zoning board, related to zoning
issues at the plant, no date has been set to mobilize Fagen,
Inc., the design builder for the project, to start the next
phase of construction for the Grinnell plant. A majority of the
contested issues were favorably decided for Big River on summary
judgment, with Big River prevailing on the remaining issues at
trial in September 2007. However, the plaintiff has
requested a reconsideration of the decision, and if the
plaintiff is unsuccessful, the Company believes that an appeal
is likely. We have not provided significant additional funding
for the Grinnell plant since our initial investment in February
2007.
All of our plants that are either operating or under
construction are designed, engineered and constructed by Fagen,
Inc., using ICM, Inc. processing technology. We have entered
into master design-build agreements with Fagen, Inc., that
provide us with a number of build slots for additional ethanol
plants through 2010. We are continuing to evaluate potential
future opportunities for development.
We have one reportable segment, our Production segment, with
other activities recorded in the All Other category. Our
Production segment includes our plants that are either currently
manufacturing ethanol or are being constructed for that purpose.
The activities of our marketing and services entities and
corporate functions are combined in the All Other category for
segment reporting purposes.
EXECUTIVE
OVERVIEW
We recorded net income of $11.1 million, or $0.15 per basic
share, for the three months ended September 30, 2007,
compared to net income of $2.5 million, or $0.04 per basic
share, for the three months ended September 30, 2006. Our
gross profits increased $19.2 million to $28.8 million
for the three months ended September 30, 2007, compared to
$9.6 million for the three months ended September 30,
2006. Our net revenues increased $116.7 million to
$150.0 million for the three months ended
September 30, 2007, compared to $33.3 million for the
three months ended September 30, 2006.
For the nine months ended September 30, 2007, we recorded
net income of $24.6 million, or $0.35 per basic share,
compared to a net loss of $0.5 million, or $0.01 per basic
share, for the nine months ended September 30, 2006. Our
gross profits increased by $49.5 million to
$66.1 million in the nine months ended September 30,
2007, compared to $16.6 million for the nine months ended
September 30, 2006. For the nine months ended
September 30, 2007, our net revenues increased
$376.3 million to $436.7 million, compared to total
net revenues of $60.4 million for the nine months ended
September 30, 2006.
The following significant items affected the comparability of
our recorded results for the three and nine months ended
September 30, 2007 and 2006, and our financial position as
of September 30, 2007:
In May 2006, the sale of ethanol and distillers grains became
the primary source of our revenues when we acquired Platte
Valley, our first ethanol production plant. In September 2006,
our Woodbury plant began operations, in November 2006, we
completed the expansion of our Platte Valley plant and in
December 2006, our Albert City plant began operations. In May
2007, we commenced operation at our Ord plant. Prior to
May 1, 2006, we derived our revenues primarily from UBE,
our marketing and
20
services businesses. As a result of the growth of our ethanol
and distillers grains production business, our results of
operations and financial condition for the three and nine months
ended September 30, 2007, are not comparable to our results
of operations and financial condition for the corresponding
periods in 2006.
In December 2006, we completed our initial public offering
(IPO), in which we sold 11,500,000 shares of our common
stock at a price to the public of $14.00 per share. Net proceeds
of the IPO, after deducting the underwriters discount and
commissions, were $149.7 million. Our common stock is
currently traded on the NASDAQ Global Market under the symbol
USBE.
In 2006, we began construction on two ethanol plants near
Hankinson, North Dakota and Dyersville, Iowa.
In January 2007, we began construction on an ethanol plant near
Janesville, Minnesota.
In February 2007, we entered into five senior secured credit
facilities with AgStar Financial Services, PCA, (AgStar) as
administrative agent and as a lender, and a group of other
lenders to provide financing for our Hankinson, Janesville,
Dyersville and Ord construction projects and to refinance our
Platte Valley credit facilities.
In February 2007, we formed Grinnell, a joint venture company,
with Big River to develop, construct, own and operate an ethanol
plant near Grinnell, Iowa. We account for this investment on a
consolidated basis because it is a variable interest entity and
we are its primary beneficiary.
In May 2007, we commenced operations at our ethanol plant
located in Ord, Nebraska.
In August 2007, we completed the acquisition of Millennium
Ethanol, LLC (Millennium) for total aggregate consideration of
$130.9 million, which was comprised of
11,292,168 shares of our common stock and
$11.6 million of cash. We changed the name to US Bio
Marion, LLC (Marion) upon completion of the acquisition. Marion
is currently constructing an ethanol plant near Marion, South
Dakota.
21
CONSOLIDATED
RESULTS
The operating results for the three and nine months ended
September 30, 2007, are not comparable to the results of
the three and nine months ended September 30, 2006, due to
the growth of our ethanol and distillers grains production
business. Our 2007 operating results include a full nine months
of operations at our Albert City and Woodbury plants and our
expanded Platte Valley plant and approximately five months of
operations at our Ord plant. The acquisition of Platte Valley on
April 30, 2006, initiated the operations of our Production
segment; therefore, the 2006 results for our Production segment
do not constitute a complete year of production activity for any
of our plants currently in operation. The following table
presents the consolidated income as well as the percentage
relationship to total revenues of specified items in our
consolidated statements of operations:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Three Months Ended September 30,
|
|
|
|
2007
|
|
|
2006
|
|
|
|
(Unaudited, dollars in thousands)
|
|
|
Total revenues
|
|
$
|
150,045
|
|
|
|
100.0
|
%
|
|
$
|
33,250
|
|
|
|
100.0
|
%
|
Total cost of goods sold
|
|
|
121,260
|
|
|
|
80.8
|
|
|
|
23,668
|
|
|
|
71.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
28,785
|
|
|
|
19.2
|
|
|
|
9,582
|
|
|
|
28.8
|
|
Selling, general and administrative expenses
|
|
|
10,846
|
|
|
|
7.3
|
|
|
|
7,233
|
|
|
|
21.7
|
|
Loss on impairment of assets
|
|
|
2,471
|
|
|
|
1.6
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
|
15,468
|
|
|
|
10.3
|
|
|
|
2,349
|
|
|
|
7.1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(1,425
|
)
|
|
|
(0.9
|
)
|
|
|
(928
|
)
|
|
|
(2.8
|
)
|
Interest income
|
|
|
1,257
|
|
|
|
0.8
|
|
|
|
694
|
|
|
|
2.1
|
|
Other income
|
|
|
7
|
|
|
|
|
|
|
|
16
|
|
|
|
|
|
Equity in net income (loss) of unconsolidated subsidiary
|
|
|
1,094
|
|
|
|
0.7
|
|
|
|
(76
|
)
|
|
|
(0.2
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes and minority interest
|
|
|
16,401
|
|
|
|
10.9
|
|
|
|
2,055
|
|
|
|
6.2
|
|
Income tax expense
|
|
|
(5,330
|
)
|
|
|
(3.5
|
)
|
|
|
|
|
|
|
|
|
Minority interest in net loss of subsidiary
|
|
|
7
|
|
|
|
|
|
|
|
455
|
|
|
|
1.3
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
11,078
|
|
|
|
7.4
|
%
|
|
$
|
2,510
|
|
|
|
7.5
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Nine Months Ended September 30,
|
|
|
|
2007
|
|
|
2006
|
|
|
|
(Unaudited, dollars in thousands)
|
|
|
Total revenues
|
|
$
|
436,666
|
|
|
|
100.0
|
%
|
|
$
|
60,364
|
|
|
|
100.0
|
%
|
Total cost of goods sold
|
|
|
370,528
|
|
|
|
84.9
|
|
|
|
43,769
|
|
|
|
72.5
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
66,138
|
|
|
|
15.1
|
|
|
|
16,595
|
|
|
|
27.5
|
|
Selling, general and administrative expenses
|
|
|
28,612
|
|
|
|
6.6
|
|
|
|
17,725
|
|
|
|
29.4
|
|
Loss on impairment of assets
|
|
|
2,471
|
|
|
|
0.5
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income (loss)
|
|
|
35,055
|
|
|
|
8.0
|
|
|
|
(1,130
|
)
|
|
|
(1.9
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(8,238
|
)
|
|
|
(1.9
|
)
|
|
|
(1,370
|
)
|
|
|
(2.3
|
)
|
Interest income
|
|
|
5,643
|
|
|
|
1.4
|
|
|
|
1,624
|
|
|
|
2.7
|
|
Other income
|
|
|
4,022
|
|
|
|
0.9
|
|
|
|
38
|
|
|
|
0.1
|
|
Equity in net income (loss) of unconsolidated subsidiary
|
|
|
2,182
|
|
|
|
0.5
|
|
|
|
(76
|
)
|
|
|
(0.1
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) before income taxes and minority interest
|
|
|
38,664
|
|
|
|
8.9
|
|
|
|
(914
|
)
|
|
|
(1.5
|
)
|
Income tax expense
|
|
|
(14,117
|
)
|
|
|
(3.3
|
)
|
|
|
|
|
|
|
|
|
Minority interest in net loss of subsidiary
|
|
|
58
|
|
|
|
|
|
|
|
391
|
|
|
|
0.6
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$
|
24,605
|
|
|
|
5.6
|
%
|
|
$
|
(523
|
)
|
|
|
(0.9
|
)%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
22
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
|
September 30,
|
|
|
|
2007
|
|
|
2006
|
|
|
|
(Unaudited)
|
|
|
Additional
Data:
(1)(8)
|
|
|
|
|
|
|
|
|
Ethanol sold (gallons in thousands)
|
|
|
73,178
|
|
|
|
14,252
|
|
Ethanol average price per
gallon
(2)(3)
|
|
$
|
1.76
|
|
|
$
|
1.90
|
|
Distillers grains average sales per gallon of ethanol
sold
(4)
|
|
$
|
0.25
|
|
|
$
|
0.21
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
2.01
|
|
|
$
|
2.11
|
|
Corn costs per gallon of ethanol
sold
(5)
|
|
$
|
1.10
|
|
|
$
|
0.76
|
|
Natural gas costs per gallon of ethanol
sold
(6)
|
|
$
|
0.13
|
|
|
$
|
0.24
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
1.23
|
|
|
$
|
1.00
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
0.78
|
|
|
$
|
1.11
|
|
|
|
|
|
|
|
|
|
|
Corn costs per
bushel
(7)
|
|
$
|
3.15
|
|
|
$
|
1.99
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
|
2007
|
|
|
2006
|
|
|
|
(Unaudited)
|
|
|
Additional
Data:
(1)(8)
|
|
|
|
|
|
|
|
|
Ethanol sold (gallons in thousands)
|
|
|
199,972
|
|
|
|
21,536
|
|
Ethanol average price per
gallon
(2)(3)
|
|
$
|
1.86
|
|
|
$
|
1.90
|
|
Distillers grains average sales per gallon of ethanol
sold
(4)
|
|
$
|
0.25
|
|
|
$
|
0.22
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
2.11
|
|
|
$
|
2.12
|
|
Corn costs per gallon of ethanol
sold
(5)
|
|
$
|
1.25
|
|
|
$
|
0.79
|
|
Natural gas costs per gallon of ethanol
sold
(6)
|
|
$
|
0.17
|
|
|
$
|
0.22
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
1.42
|
|
|
$
|
1.01
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
0.69
|
|
|
$
|
1.11
|
|
|
|
|
|
|
|
|
|
|
Corn costs per
bushel
(7)
|
|
$
|
3.58
|
|
|
$
|
2.12
|
|
|
|
|
(1)
|
|
The 2006 data represents the period beginning May 1, 2006
through September 30, 2006, after our acquisition of the
Platte Valley plant and approximately one month of operations at
our Woodbury plant.
|
|
(2)
|
|
The 2007 data represents the gross sales dollars, net of freight
and commissions, divided by the gallons of ethanol sold. Freight
and commissions were $0.17 per gallon for both the three and
nine months ended September 30, 2007, respectively.
|
|
(3)
|
|
The 2006 data represents the gross sales dollars, before netting
freight and commissions, divided by the gallons of ethanol sold.
(See net sales of ethanol in the three and nine month
discussions below).
|
|
(4)
|
|
Represents the gross sales dollars, net of commissions, divided
by the gallons of ethanol sold.
|
|
(5)
|
|
Represents the corn costs, including freight, commissions,
hedging gains or losses and other related costs divided by the
gallons of ethanol sold.
|
|
(6)
|
|
Represents natural gas costs, including hedging gains or losses,
divided by the gallons of ethanol sold.
|
|
(7)
|
|
Represents corn costs, net of hedging gains of $0.43 and $0.05
per bushel for the three and nine months ended
September 30, 2007, respectively, and hedging gains of
$0.17 and $0.03 per bushel for the three and nine months ended
September 30, 2006, respectively.
|
|
(8)
|
|
Certain numbers related to the three and nine month production
results of 2006 have been adjusted to conform to the method of
calculation utilized in the three and nine month production
results of 2007.
|
23
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Three Months Ended September 30,
|
|
|
|
2007
|
|
|
2006
|
|
|
|
|
|
|
Average Price
|
|
|
|
|
|
Average Price
|
|
|
|
Tons
|
|
|
per Ton
|
|
|
Tons
|
|
|
per Ton
|
|
|
Distillers Grains Sales Data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Dried distillers grains (DDG)
|
|
|
61,100
|
|
|
$
|
97.10
|
|
|
|
5,300
|
|
|
$
|
75.39
|
|
Modified wet distillers grains (MWDG)
|
|
|
276,800
|
|
|
$
|
39.39
|
|
|
|
71,400
|
|
|
$
|
36.82
|
|
Wet distillers grains (WDG)
|
|
|
7,800
|
|
|
$
|
26.94
|
|
|
|
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Nine Months Ended September 30,
|
|
|
|
2007
|
|
|
2006
|
|
|
|
|
|
|
Average Price
|
|
|
|
|
|
Average Price
|
|
|
|
Tons
|
|
|
per Ton
|
|
|
Tons
|
|
|
per Ton
|
|
|
Distillers Grains Sales Data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Dried distillers grains (DDG)
|
|
|
201,800
|
|
|
$
|
99.87
|
|
|
|
5,300
|
|
|
$
|
75.39
|
|
Modified wet distillers grains (MWDG)
|
|
|
692,600
|
|
|
$
|
42.58
|
|
|
|
115,600
|
|
|
$
|
37.22
|
|
Wet distillers grains (WDG)
|
|
|
20,000
|
|
|
$
|
34.15
|
|
|
|
|
|
|
$
|
|
|
Three
Months Ended September 30, 2007 compared to Three Months
Ended September 30, 2006
Total Revenues.
Total revenues increased by
$116.7 million to $150.0 million for the three months
ended September 30, 2007, compared to $33.3 million
for the three months ended September 30, 2006, primarily as
a result of the continued growth of our ethanol production
business. The revenues for the three months ended
September 30, 2007, represent a full quarter of production
activity at our Albert City, Woodbury, Platte Valley and Ord
plants compared to one full quarter of production activity at
the Platte Valley plant and approximately one month of
operations at our Woodbury plant in our results for the three
months ended September 30, 2006.
Net sales of ethanol increased by $102.0 million to
$129.0 million for the three months ended
September 30, 2007, from $27.0 million for the three
months ended September 30, 2006. During the third quarter
of 2007, our Production segment sold 73.2 million gallons
of ethanol at an average selling price of $1.76 per gallon,
compared to the third quarter of 2006, when we sold
14.3 million gallons of ethanol at an average selling price
of $1.90 per gallon. Sales for the three months ended
September 30, 2007, are net of transportation costs of
$10.6 million, or $0.14 per gallon, and commissions of
$2.0 million, or $0.03 per gallon. As of September 2006, we
discontinued consolidating the operations of Provista and, as
such, the sales from that time forward are recorded on a net
basis.
Net sales of co-products increased $15.9 million to
$19.0 million for the three months ended September 30,
2007, compared to $3.1 million for the three months ended
September 30, 2006, due to a 269,000 ton increase in volume
sold and an increase in the average net selling prices. During
the third quarter of fiscal 2007, our Production segment sold
61,100 tons of dried distillers grains at an average selling
price of $97.10 per ton, 276,800 tons of modified wet distillers
grains at an average selling price of $39.39 per ton and 7,800
tons of wet distillers grains at an average selling price of
$26.94 per ton. In the third quarter of 2006, our Production
segment sold 5,300 tons of dried distillers grains at an average
selling price of $75.39 per ton and 71,400 tons of modified wet
distillers grains at an average selling price of $36.82 per ton.
Sales of co-products represented $0.25 per gallon of ethanol
sold for the three months ended September 30, 2007,
compared to $0.21 per gallon of ethanol sold for the three
months ended September 30, 2006.
Sales of other products decreased $0.2 million, or 39%, to
$0.3 million for the three months ended September 30,
2007, from $0.5 million for the three months ended
September 30, 2006, primarily as the result of decreased
sales of non-fixed margin commodities in our marketing and
services business.
Services and commissions revenues increased $0.4 million,
or 30%, to $1.5 million for the three months ended
September 30, 2007, from $1.1 million for the three
months ended September 30, 2006.
24
Other revenue decreased $1.3 million, or 85%, to
$0.2 million for the three months ended September 30,
2007, compared to $1.5 million for the three months ended
September 30, 2006, due to the timing of incentive credits
earned under the State of Nebraskas ethanol incentive
program. In 2007, we earned our incentive credits sooner than in
2006 due to the expansion of our Platte Valley plant. Our Platte
Valley plant generates alcohol fuel tax incentive credits at a
rate of $0.18 per gallon on the first 15,625,000 gallons of
ethanol produced on a yearly basis beginning on
May 1st of each year. This state incentive program is
set to expire in 2012.
Cost of Goods Sold.
Cost of goods sold
increased by $97.6 million to $121.3 million for the
three months ended September 30, 2007, from
$23.7 million for the three months ended September 30,
2006, primarily as the result of the growth in our ethanol and
distillers grains production business and lower natural gas
prices, which were partially offset by higher corn prices. Cost
of goods sold in our Production segment represented $1.62 per
gallon of ethanol sold for the three months ended
September 30, 2007, compared to $1.54 per gallon of ethanol
sold for the three months ended September 30, 2006. Ethanol
cost of goods sold, which represents cost of goods sold less
distillers grains revenues, was $1.37 per gallon for the three
months ended September 30, 2007, compared to $1.33 per
gallon for the three months ended September 30, 2006.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Three Months Ended September 30,
|
|
|
|
2007
|
|
|
2006
|
|
|
|
Per Bushel
|
|
|
Per Gallon
|
|
|
Per Bushel
|
|
|
Per Gallon
|
|
|
Corn costs:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
No hedging impact
|
|
$
|
3.58
|
|
|
$
|
1.25
|
|
|
$
|
2.16
|
|
|
$
|
0.82
|
|
Hedging (gains)
|
|
|
(0.43
|
)
|
|
|
(0.15
|
)
|
|
|
(0.17
|
)
|
|
|
(0.06
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
With hedging impact
|
|
$
|
3.15
|
|
|
$
|
1.10
|
|
|
$
|
1.99
|
|
|
$
|
0.76
|
|
Natural gas costs:
|
|
|
Per MMBTU
|
|
|
|
Per Gallon
|
|
|
|
Per MMBTU
|
|
|
|
Per Gallon
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
No hedging impact
|
|
$
|
5.25
|
|
|
$
|
0.13
|
|
|
$
|
6.54
|
|
|
$
|
0.17
|
|
Hedging losses
|
|
|
|
|
|
|
|
|
|
|
2.94
|
|
|
|
0.07
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
With hedging impact
|
|
$
|
5.25
|
|
|
$
|
0.13
|
|
|
$
|
9.48
|
|
|
$
|
0.24
|
|
Corn costs were $80.5 million for the three months ended
September 30, 2007, and represented 67% of our cost of
goods sold, compared to $10.9 million and 49% of our cost
of goods sold for the three months ended September 30,
2006. This increase in costs was primarily due to increased
volumes of corn processed and an average price, net of hedging
gains, that was $1.16 per bushel higher than the corresponding
period in 2006.
Natural gas costs were $9.5 million for the three months
ended September 30, 2007, and represented 8% of our cost of
goods sold, compared to $3.4 million and 16% of our cost of
goods sold for the three months ended September 30, 2006.
The increased utilization of natural gas is due to the increase
in production as a result of the growth of our business, which
was partially offset by a decrease of $4.23 MMBTU in the
average price, net of hedging losses, compared to the
corresponding period in 2006.
Transportation costs were $1.7 million for the three months
ended September 30, 2007, and represented 1% of our cost of
goods sold, compared to $2.3 million and 10% of cost of
goods sold for the three months ended September 30, 2006.
All of the transportation costs of $1.7 million for the
three months ended September 30, 2007, are related to
shipments of distillers grains, which compared to $54,000 for
the three months ended September 30, 2006. Shipments of
distillers grains increased as a result of the growth in our
volume sold. For the three months ended September 30, 2007,
we recorded our ethanol sales net of related transportation
costs as Provista incurred those costs. For the three months
ended September 30, 2006, we recorded $2.2 million of
ethanol related transportation costs in cost of goods sold, due
to the consolidation of Provista.
Labor and manufacturing overhead was $26.1 million for the
three months ended September 30, 2007, and represented 23%
of our cost of goods sold, compared to $5.4 million and 25%
of cost of goods sold for the three months ended
September 30, 2006. Labor and manufacturing overhead
represented $0.35 per gallon
25
for the three months ended September 30, 2007, compared to
$0.45 per gallon for the three months ended September 30,
2006. Construction related labor costs incurred during the
construction phase of our ethanol plants are considered to be
part of the direct cost of construction and, as such, are
capitalized.
Hedging losses on exchange-traded energy futures contracts were
$1.5 million, or $0.02 per gallon, for the three months
ended September 30, 2007, and represented 1% of our cost of
goods sold. We did not enter into any exchange-traded energy
futures contracts in 2006.
The aggregate net gain from derivatives included in cost of
goods sold was $9.3 million for the three months ended
September 30, 2007, compared to a $0.1 million loss
for the three months ended September 30, 2006. We mark all
exchange-traded corn, natural gas and energy futures contracts
to market through cost of goods sold. For the three months ended
September 30, 2007, net gains on hedging activities were
$0.13 per gallon, compared to a $0.01 per gallon net loss on
hedging activities for the three months ended September 30,
2006.
Cost of products sales related to the commodities that we sell
under non-fixed margin contracts increased $0.6 million to
$1.1 million for the three months ended September 30,
2007, from $0.5 million for three months ended
September 30, 2006.
Cost of services and commissions decreased by $0.5 million,
or 40%, to $0.8 million for the three months ended
September 30, 2007, from $1.3 million for the three
months ended September 30, 2006, primarily due to the
deconsolidation of Provista.
Gross Profit.
Gross profit increased by
$19.2 million to $28.8 million for the three months
ended September 30, 2007, from $9.6 million for the
three months ended September 30, 2006, driven primarily by
the expansion of our Platte Valley plant and the commencement of
operations at our Albert City, Ord and Woodbury plants, hedging
gains and a decrease in natural gas prices, which were partially
offset by higher corn prices. For the three months ended
September 30, 2007, our Production segment generated gross
profit of $28.1 million, or $0.39 per gallon, compared to
$9.6 million, or $0.61 per gallon, for the three months
ended September 30, 2006. Gross profit for the three months
ended September 30, 2007, decreased $0.22 per gallon
compared to the three months ended September 30, 2006,
primarily due to higher corn costs, which was partially offset
by lower natural gas costs.
Selling, General and Administrative
Expenses.
Our selling, general and administrative
expenses increased $3.6 million, or 50%, to
$10.8 million for the three months ended September 30,
2007, from $7.2 million for the three months ended
September 30, 2006. Expenses in the All Other segment
category increased by $4.0 million, primarily due to the
growth of our businesses, which was partially offset by
decreased expenses of $0.4 million in our Production
segment.
Loss on Impairment of Assets.
In September
2007, we determined that based on future cash flows, the
carrying amount of the goodwill and intangible assets which were
assigned to UBE, our marketing and services business, exceed the
fair value by $2.5 million. At that time we recorded an
expense of $2.5 million in the All Other segment category
to impair $1.8 million of goodwill and $0.7 million of
intangible assets (Refer to Footnote 12 for more detail).
Interest Expense.
Interest expense increased
by $0.5 million, or 54%, to $1.4 million for the three
months ended September 30, 2007, from $0.9 million for
the three months ended September 30, 2006, primarily due to
additional borrowings on our senior secured credit facilities.
Interest expense for the three months ended September 30,
2006, represented interest on borrowings under credit facilities
primarily related to Provista, which have since been repaid and
terminated in connection with the transfer of our 50% ownership
interest to CHS. Interest costs of $4.2 million and
$1.0 million incurred on borrowings related to construction
activities were capitalized for the three months ended
September 30, 2007 and 2006, respectively, and, as such,
are not included in interest expense. Total interest costs for
the three months ended September 30, 2007 were
$5.6 million, compared to $1.9 million for the three
months ended September 30, 2006.
26
Interest Income.
Interest income increased by
$0.6 million, or 81%, to $1.3 million for the three
months ended September 30, 2007, from $0.7 million for
the three months ended September 30, 2006, primarily as the
result of increased short-term investments from excess cash
flows generated by our Production segment.
Equity in Net Income (Loss) of Subsidiary.
Our
equity in net income of unconsolidated subsidiary of
$1.1 million for the three months ended September 30,
2007, represented our 50% share of Provistas results.
Beginning September 1, 2006, we accounted for our
investment in Provista under the equity method of accounting.
The net loss for this period was $76,000.
Income Before Income Taxes and Minority
Interest.
Pretax income increased by
$14.3 million to $16.4 million for the three months
ended September 30, 2007, from $2.1 million for the
three months ended September 30, 2006, which is primarily
due to the increase in production volumes as our ethanol plants
began operations.
Income Taxes.
Income tax expense of
$5.3 million for the three months ended September 30,
2007, represented an effective tax rate of 32.5%, and included a
$1.0 million benefit (net of federal tax effect) due to a
reversal of a deferred tax asset valuation allowance related to
state tax credits. We recorded income tax expense of
$1.0 million for the three months ended September 30,
2006, which was offset by a $1.0 million valuation
allowance.
Minority Interest in Net Loss of
Subsidiary.
Minority interest in net loss of
subsidiary was $7,000 for the three months ended
September 30, 2007, and represented the minority
owners 50% share of losses of Grinnell. In February 2007,
we formed a joint venture with Big River and began to
consolidate the operations of the joint venture. Minority
interest in net loss of subsidiary was $0.5 million for the
three months ended September 30, 2006, and represented the
minority owners 50% share of Provistas net losses.
On March 31, 2006, we sold 50% of our membership interest
in Provista to CHS. For the period beginning April 1, 2006,
and ending August 31, 2006, we consolidated the operations
of Provista because it was a variable interest entity and we
were the primary beneficiary of a significant receivable owed to
us by Provista and we guaranteed Provistas debt. On
August 31, 2006, our guarantee of Provistas debt was
terminated and Provista repaid all outstanding debts to us, and
we deconsolidated Provista. From September 1, 2006, forward
we are accounting for our investment in Provista under the
equity method of accounting.
Nine
Months Ended September 30, 2007 compared to Nine Months
Ended September 30, 2006
Total Revenues.
Total revenues increased by
$376.3 million to $436.7 million for the nine months
ended September 30, 2007, compared to $60.4 million
from the nine months ended September 30, 2006, primarily as
the result of increased production as our new plants became
operational. Revenues for the nine months ended
September 30, 2007, represents nine months of production
activity at Albert City, Platte Valley and Woodbury, and almost
two full quarters of production at our Ord plant, compared to
2006 results which reflected five months of production activity
at Platte Valley before the expansion, and one month of
operations at Woodbury.
Net sales of ethanol increased by $327.8 million to
$371.4 million for the nine months ended September 30,
2007, from $43.6 million for the nine months ended
September 30, 2006. For the three quarters of 2007, our
Production segment sold 200.0 million gallons of ethanol at
an average selling price of $1.86 per gallon compared to 2006,
when we sold 21.5 million gallons of ethanol at an average
selling price of $1.90 per gallon. Sales for the nine months
ended September 30, 2007, are net of transportation costs
of $28.1 million, or $0.14 per gallon, and commissions of
$5.6 million, or $0.03 per gallon. As of September 2006, we
discontinued consolidating the operations of Provista and, as
such, the sales from that time forward are recorded on a net
basis.
Net sales of co-products increased $48.0 million to
$53.1 million for the nine months ended September 30,
2007, from $5.1 million for the nine months ended
September 30, 2006 due to an increase in volume sold of
793,500 tons and an increase in the average net selling prices.
During the nine months ended September 30, 2007, our
Production segment sold 201,800 tons of dried distillers grains
at an average selling price of $99.87 per ton, 692,600 tons of
modified wet distillers grains at an average selling price of
$42.58 per ton and 20,000 tons of wet distillers grains at an
average selling price of $34.15 per ton. In the period beginning
May 1, 2006
27
through September 30, 2006, our Production segment sold
5,300 tons of dried distillers grains at an average selling
price of $75.39 per ton and 115,600 tons of modified wet
distillers grains at an average selling price of $37.22 per ton.
Sales of co-products represented $0.25 per gallon of ethanol
sold for the nine months ended September 30, 2007, compared
to $0.22 per gallon of ethanol sold for the nine months ended
September 30, 2006.
Sales of other products decreased by $0.2 million, or 7%,
to $3.0 million for the nine months ended
September 30, 2007, from $3.2 million for the nine
months ended September 30, 2006. For the nine months ended
September 30, 2007, we recorded revenues of
$1.7 million from the sale of yellow corn. This increase
was offset by decreased sales of non-fixed margin commodities of
$1.9 million in our marketing and services business.
Services and commissions revenues increased $0.6 million,
or 12%, to $6.3 million for the nine months ended
September 30, 2007, from $5.7 million for the nine
months ended September 30, 2006. In the second quarter of
2007, we recorded $0.2 million of revenue related to the
termination of a management agreement with a third-party plant
customer.
Other revenue remained consistent at $2.8 million for the
nine months ended September 30, 2007 and 2006. Our Platte
Valley plant generates alcohol fuel tax incentive credits under
the State of Nebraskas ethanol incentive program at a rate
of $0.18 per gallon on the first 15,625,000 gallons of ethanol
produced on a yearly basis beginning on May 1st of
each year. This state incentive program is set to expire in 2012.
Cost of Goods Sold.
Cost of goods sold
increased by $326.7 million to $370.5 million for the
nine months ended September 30, 2007, from
$43.8 million for the nine months ended September 30,
2006, as a result of the growth in our ethanol and distillers
grains production business, as well as lower natural gas prices,
which were partially offset by increased corn prices. Cost of
goods sold in our Production segment represented $1.83 per
gallon of ethanol sold for the nine months ended
September 30, 2007, compared to $1.60 per gallon of ethanol
sold for the nine months ended September 30, 2006. This per
gallon increase was primarily driven by higher corn prices,
which were partially offset by decreased natural gas prices.
Ethanol cost of goods sold, which represents cost of goods sold
less distillers grains revenues, was $1.58 per gallon for the
nine months ended September 30, 2007, compared to $1.38 per
gallon for the nine months ended September 30, 2006.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Nine Months Ended September 30,
|
|
|
|
2007
|
|
|
2006
|
|
|
|
Per Bushel
|
|
|
Per Gallon
|
|
|
Per Bushel
|
|
|
Per Gallon
|
|
|
Corn costs:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
No hedging impact
|
|
$
|
3.63
|
|
|
$
|
1.27
|
|
|
$
|
2.15
|
|
|
$
|
0.80
|
|
Hedging (gains)
|
|
|
(0.05
|
)
|
|
|
(0.02
|
)
|
|
|
(0.03
|
)
|
|
|
(0.01
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
With hedging impact
|
|
$
|
3.58
|
|
|
$
|
1.25
|
|
|
$
|
2.12
|
|
|
$
|
0.79
|
|
Natural gas costs:
|
|
|
Per MMBTU
|
|
|
|
Per Gallon
|
|
|
|
Per MMBTU
|
|
|
|
Per Gallon
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
No hedging impact
|
|
$
|
6.59
|
|
|
$
|
0.17
|
|
|
$
|
6.63
|
|
|
$
|
0.16
|
|
Hedging (gains) losses
|
|
|
(0.08
|
)
|
|
|
|
|
|
|
2.42
|
|
|
|
0.06
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
With hedging impact
|
|
$
|
6.51
|
|
|
$
|
0.17
|
|
|
$
|
9.05
|
|
|
$
|
0.22
|
|
Corn costs were $250.1 million for the nine months ended
September 30, 2007, and represented 69% of our cost of
goods sold, compared to $17.0 million and 51% of our cost
of goods sold for the nine months ended September 30, 2006.
This increase in costs was primarily due to increased volumes of
corn processed and an average price, net of hedging gains, that
was $1.46 per bushel higher than the corresponding period in
2006.
Natural gas costs were $33.3 million for the nine months
ended September 30, 2007, and represented 9% of our cost of
goods sold, compared to $4.8 million and 14% of our cost of
goods sold for the nine months ended September 30, 2006.
The increased utilization of natural gas is due to the increase
in production as a result of the growth of our business, which
was partially offset by a decrease of $2.54 MMBTU in the
average price, net of hedging losses, compared to the
corresponding period in 2006.
28
Transportation costs were $5.4 million for the nine months
ended September 30, 2007, and represented 1% of our cost of
goods sold, compared to $3.6 million and 11% of cost of
goods sold for the nine months ended September 30, 2006.
All of the transportation costs of $5.4 million for the
nine months ended September 30, 2007, are related to
shipments of distillers grains, which compared to $54,000 for
the nine months ended September 30, 2006. Shipments of
distillers grains increased as a result of the growth in our
volume sold. For the nine months ended September 30, 2007,
we recorded our ethanol sales net of related transportation
costs as Provista incurred those costs. For the nine months
ended September 30, 2006, we recorded $3.5 million of
ethanol related transportation costs in cost of goods sold, due
to the consolidation of Provista.
Labor and manufacturing overhead costs were $70.3 million
for the nine months ended September 30, 2007, and
represented 19% of our cost of goods sold, compared to
$8.0 million and 24% of cost of goods sold for the nine
months ended September 30, 2006. Labor and manufacturing
overhead costs represented $0.35 per gallon for the nine months
ended September 30, 2007, compared to $0.37 per gallon of
ethanol sold for the nine months ended September 30, 2006.
Construction related labor costs incurred during the
construction phase of our ethanol plants are considered to be
part of the direct cost of construction and, as such, are
capitalized.
Hedging losses on exchange-traded energy futures contracts were
$5.9 million, or $0.03 per gallon, for the nine months
ended September 20, 2007, and represented 1% of our cost of
goods sold. We did not enter into any exchange-traded energy
contracts in 2006.
The aggregate net loss from derivatives included in cost of
goods sold was $2.0 million for the nine months ended
September 30, 2007, compared to $1.0 million for the
nine months ended September 30, 2006. We mark all
exchange-traded corn, natural gas and energy futures contracts
to market through cost of goods sold. For the nine months ended
September 30, 2007, net losses on hedging activities were
$0.1 per gallon of ethanol sold compared to $0.05 per gallon of
ethanol sold for the nine months ended September 30, 2006.
Cost of product sales related to the commodities that we sell
under non-fixed margin contracts decreased $3.4 million, or
54%, to $2.8 million for the nine months ended
September 30, 2007, from $6.2 million for the nine
months ended September 30, 2006.
Cost of services and commissions decreased by $1.6 million,
or 38%, to $2.7 million for the nine months ended
September 30, 2007, from $4.3 million for the nine
months ended September 30, 2006, primarily due to a
reduction in employee costs in our marketing and services
business partially due to the deconsolidation of Provista.
Gross Profit.
Gross profit increased
$49.5 million to $66.1 million for the nine months
ended September 30, 2007, from $16.6 million for the
nine months ended September 30, 2006, driven primarily by
the acquisition and expansion of our Platte Valley plant and the
commencement of operations at our Albert City, Woodbury and Ord
plants and lower natural gas prices, which was partially offset
by higher corn prices. We generated gross profit of
$62.4 million, or $0.30 per gallon, in our Production
segment compared to $14.9 million, or $0.65 per gallon for
the nine months ended September 30, 2006. Gross profit for
the nine months ended September 30, 2007, decreased $0.35
per gallon compared to the nine months ended September 30,
2006, primarily due to higher corn prices, which was partially
offset by decreased natural gas prices.
Selling, General and Administrative
Expenses.
Our selling, general and administrative
expenses increased $10.9 million, or 61%, to
$28.6 million for the nine months ended September 30,
2007, from $17.7 million for the nine months ended
September 30, 2006. Expenses in the All Other segment
category increased by $9.6 million. Of this amount,
$14.4 million was primarily due to the growth of our
businesses, partially offset by a one-time payment of
$4.8 million in May of 2006 to Capitaline Advisors, LLC, (a
related party) in connection with the termination of a financial
advisory services agreement. Expenses in our Production segment
increased by $1.3 million, primarily due to our additional
production plants.
Loss on Impairment of Assets.
In September
2007, we determined that based on future cash flows, the
carrying amount of the goodwill and intangible assets which were
assigned to UBE, our marketing and
29
services business, exceed the fair value by $2.5 million.
At that time we recorded an expense of $2.5 million in the
All Other segment category to impair $1.8 million of
goodwill and $0.7 million of intangible assets. (Refer to
Footnote 12 for more detail).
Interest Expense.
Interest expense increased
by $6.9 million to $8.2 million for the nine months
ended September 30, 2007, from $1.4 million for the
nine months ended September 30, 2006, primarily due to
additional borrowings on our senior secured credit facilities.
In connection with the refinancing of Platte Valleys debt,
we expensed a prepayment penalty of $0.7 million and
$0.7 million of debt financing costs. Interest expense for
the nine months ended September 30, 2006, represented
interest on borrowing under credit facilities primarily related
to Provista, which have since been repaid and terminated in
connection with the transfer of our 50% ownership interest to
CHS. Interest costs of $9.0 million and $1.2 million
incurred on borrowing related to construction activities were
capitalized for the nine months ended September 30, 2007
and 2006, respectively, and, as such, are not included in
interest expense. Total interest costs for the nine months ended
September 30, 2007 were $17.2 million, compared to
$2.6 million for the nine months ended September 30,
2006.
Interest Income.
Interest income increased by
$4.0 million to $5.6 million for the nine months ended
September 30, 2007, compared to $1.6 million for the
nine months ended September 30, 2006. This increase was
primarily the result of increased short-term investments arising
from the proceeds of our initial public offering and from excess
cash flows generated by our Production segment.
Other Income.
Other income of
$4.0 million for the nine months ended September 30,
2007, compared to a minimal amount for the nine months ended
September 30, 2006. This increase is the result of the
receipt of the remaining $4.0 million due to us from the
sale of a construction build slot. In December 2006, we sold one
of our build slots under a master design-build agreement with
Fagen, Inc. for total consideration of $12.0 million. We
received and recognized $8.0 million in December 2006, upon
execution of the agreement. The remaining $4.0 million was
received when Fagen, Inc. mobilized at the build site.
Equity in Net Income (Loss) of Subsidiary.
Our
equity in net income of unconsolidated subsidiary of
$2.2 million for the nine months ended September 30,
2007, compared to a $76,000 net loss for the one month
ended September 30, 2006, and represented our 50% share of
Provistas results. Beginning September 1, 2006, we
account for our investment in Provista under the equity method
of accounting.
Income (Loss) Before Income Taxes and Minority
Interest.
Pretax income increased by
$39.6 million to $38.7 million for the nine months
ended September 30, 2007, compared to a loss of
$0.9 million for the nine months ended September 30,
2006. Our Production segments pretax income increased
$30.4 million, primarily due to the growth in our
production business. In addition, we recognized other income due
to the receipt of $4.0 million from the sale of the build
slot as described above.
Income Taxes.
Income tax expense of
$14.1 million for the nine months ended September 30,
2007, represented an effective tax rate of 36.5%, and included a
$1.0 million benefit (net of federal tax effect) due to a
reversal of a deferred tax asset valuation allowance related to
state tax credits. We recorded an income tax benefit of
$0.1 million related to our net loss for the nine months
ended September 30, 2006, which was offset by a
$0.1 million valuation allowance on the net loss.
Minority Interest in Net Loss of
Subsidiary.
Minority interest in net loss of
subsidiary was $58,000 for the nine months ended
September 30, 2007, and represented the minority
owners 50% of losses of Grinnell. In February 2007, we
formed a joint venture with Big River and we began to
consolidate the operations of the joint venture. Minority
interest in net loss of subsidiary was $0.4 million for the
nine months ended September 30, 2006, and represented the
minority owners 50% share of Provistas net loss. On
March 31, 2006, we sold 50% of our membership interest in
Provista to CHS. For the period beginning April 1, 2006,
and ending August 31, 2006, we consolidated the operations
of Provista because it was a variable interest entity and we
were the primary beneficiary of a significant receivable owed to
us by Provista and our guarantee of Provistas debt. On
August 31, 2006, our guarantee of Provistas debt was
terminated and Provista repaid all outstanding debts to us, and
we deconsolidated Provista. From September 1, 2006 forward
we are accounting for our investment in Provista under the
equity method of accounting.
30
LIQUIDITY
AND CAPITAL RESOURCES
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30,
|
|
|
|
2007
|
|
|
2006
|
|
|
Net cash provided by (used in) operating activities
|
|
$
|
64,101
|
|
|
$
|
(3,429
|
)
|
Net cash used in investing activities
|
|
|
(302,970
|
)
|
|
|
(171,848
|
)
|
Net cash provided by financing activities
|
|
|
148,499
|
|
|
|
202,781
|
|
|
|
|
|
|
|
|
|
|
Net (decrease) increase in cash and cash equivalents
|
|
$
|
(90,370
|
)
|
|
$
|
27,504
|
|
|
|
|
|
|
|
|
|
|
CASH
FLOWS
Cash Flows Provided by (Used in) Operating
Activities.
Cash flows provided by operating
activities totaled $64.1 million for the nine months ended
September 30, 2007, compared to cash flows used in
operating activities of $3.4 million for the nine months
ended September 30, 2006. The increase in cash provided by
operating activities is primarily driven by the growth of our
business. An increase in working capital for the nine months
ended September 30, 2007 and 2006 used cash of
$0.1 million and $6.3 million, respectively.
Cash Used in Investing Activities.
Cash used
in investing activities totaled $303.0 million and
$171.8 million for the nine months ended September 30,
2007 and 2006, respectively. For the nine months ended
September 30, 2007, additions to property and equipment of
$19.1 million, $24.7 million, $93.0 million,
$78.0 million and $44.5 million were related to
construction projects at Marion, Ord, Hankinson, Dyersville and
Janesville, respectively. Additions to property and equipment
related to Grinnells construction project were
$7.2 million, which represented 100% of costs since we
began consolidating Grinnells activities. For the nine
months ended September 30, 2006, additions to property,
plant and equipment of $30.9 million, $62.6 million,
$32.1 million and $17.7 million were related to
construction projects at Woodbury, Albert City, Platte Valley
and Ord, respectively.
Cash Provided by Financing Activities.
Cash
provided by financing activities totaled $148.5 million for
the nine months ended September 30, 2007 and
$202.8 million for the nine months ended September 30,
2006, respectively. In February 2007, we entered into five
senior secured facilities with AgStar to provide funds for
construction of our Hankinson, Dyersville, Janesville and Ord
plants and to refinance our Platte Valley plant. On
August 29, 2007, we acquired the senior construction credit
facility that Millennium had entered into with Dougherty
Funding, LLC (Dougherty). For the nine months ended
September 30, 2007, we borrowed an aggregate of
$61.8 million to fund our Hankinson, Dyersville, Janesville
and Marion construction projects. In February 2007, we borrowed
an additional $51.6 million on our Platte Valley senior
secured credit facility when we refinanced with AgStar. In
addition, we borrowed an additional $10.9 million when we
converted our Albert City construction loan to term loans. In
March 2006, we raised approximately $94.4 million through a
private placement of our common stock. In August 2006, we
borrowed an aggregate of $99.5 million under our
construction loans for our Albert City and Woodbury plants and
for our expansion project at Platte Valley.
Significant sources of liquidity during the nine months ended
September 30, 2007, included proceeds from our IPO,
borrowings under our credit facilities and cash provided by
operations. During the nine months ended September 30,
2006, our private placement equity offerings were the
significant source of liquidity.
Our principal uses of cash have been, and are expected to
continue to be, the construction of new plants, other capital
expenditures and payments on our outstanding indebtedness. As of
September 30, 2007, we had total cash and cash equivalents
of $79.7 million, compared to $68.0 million as of
September 30, 2006. Of the $79.7 million, an aggregate
of $46.2 million was held by certain of our subsidiaries,
which are generally limited in their ability to pay dividends or
make distributions to us by the terms of their financing
agreements.
31
PRODUCTION
CAPACITY EXPANSION
Set forth in the table below are the estimated remaining
construction costs (not including
start-up
working capital requirements) of our ethanol plants under
construction as of September 30, 2007:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Marion,
|
|
|
Hankinson,
|
|
|
Dyersville,
|
|
|
Janesville,
|
|
|
|
|
|
|
South Dakota
|
|
|
North Dakota
|
|
|
Iowa
|
|
|
Minnesota
|
|
|
Total
|
|
|
Estimated Production Start Date
|
|
|
Q1
|
|
|
|
Q2
|
|
|
|
Q2
|
|
|
|
Q3
|
|
|
|
|
|
|
|
|
2008
|
|
|
|
2008
|
|
|
|
2008
|
|
|
|
2008
|
|
|
|
|
|
Estimated Ethanol Production Capacity per year (mmgy)
|
|
|
110
|
|
|
|
110
|
|
|
|
110
|
|
|
|
110
|
|
|
|
440
|
|
Total Estimated Construction Costs
|
|
$
|
144.0
|
|
|
$
|
146.0
|
|
|
$
|
163.0
|
|
|
$
|
146.5
|
|
|
$
|
599.5
|
|
Estimated Remaining Construction Costs
|
|
$
|
38.5
|
|
|
$
|
49.4
|
|
|
$
|
79.6
|
|
|
$
|
97.6
|
|
|
$
|
265.1
|
|
Amount to be Funded Under Existing Credit Facilities
|
|
$
|
38.5
|
|
|
$
|
49.4
|
|
|
$
|
79.6
|
|
|
$
|
82.8
|
|
|
$
|
250.3
|
|
According to the terms of our AgStar senior credit facilities
for the Hankinson, Dyersville and Janesville projects described
above, generally 60% of the total construction costs are funded
with borrowings under the applicable credit facility. See
Credit Arrangements.
We intend to fund the $14.8 million of construction costs
for these plants in excess of amounts available under our credit
facilities with cash on hand and cash generated from operations.
Due to the pending zoning lawsuits previously discussed, our
Grinnell plant has not obtained the required debt financing, and
we have put on hold any further funding. Even if the lawsuits
are favorably resolved, there can be no assurance that Grinnell
will be able to obtain the required debt funding on acceptable
terms, or at all.
We are continuing to evaluate potential future opportunities for
development. Additional funding will be required to finance the
construction of any additional ethanol plants. There can be no
assurance, however, that we will be able to obtain the required
funding on terms acceptable to us, or at all.
CREDIT
ARRANGEMENTS
Albert
City
In March 2007, the Albert City construction loan was converted
to a term loan, a revolving loan, and a seasonal revolving loan,
which allows for up to $3.0 million to be used for letters
of credit. As of September 30, 2007, $64.6 million was
outstanding under the term loan and $12.6 million was
outstanding under the revolving term loan. In addition, Albert
City has a $6.5 million seasonal revolving loan that is
available for working capital needs. As of September 30,
2007, no amount was outstanding under Albert Citys
seasonal revolving loan and $2.7 million of letters of
credit were outstanding.
In November 2005, Albert City entered into a senior secured
credit facility with AgStar, as administrative agent and as a
lender, and a group of other lenders to finance the development
and construction of our Albert City ethanol plant.
In April 2005, Albert City entered into a loan agreement with
the Iowa Department of Economic Development. As of
September 30, 2007, the outstanding balance under this loan
agreement was $0.4 million.
Ord
In September 2007, the Ord construction loan was converted to a
term loan, a revolving loan, and a seasonal revolving loan,
which allows for up to $5.0 million to be used for letters
of credit. As of September 30, 2007, $34.9 million was
outstanding under the term loan and $11.6 million was
outstanding under the revolving term loan. In addition, Ord has
a $10.0 million seasonal revolving loan that is available
for working capital needs. As of September 30, 2007, no
amount was outstanding under Ords seasonal revolving loan,
and no letters of credit were outstanding.
32
In February 2007, Ord entered into a senior secured credit
facility with AgStar, as administrative agent and as a lender,
and a group of other lenders to finance the development and
construction of our Ord ethanol plant.
Platte
Valley
On February 7, 2007, Platte Valley entered into a senior
secured credit facility with AgStar, as administrative agent and
as a lender, and a group of other lenders to refinance a
$90.0 million existing credit facility for Platte Valley.
In addition, a $10.0 million seasonal revolving credit
facility is available under the senior secured credit facility,
which allows for up to $5.0 million to be used for letters
of credit. As of September 30, 2007, $65.9 million
was outstanding under the term loan, and $22.5 million was
outstanding under the revolving term loan. No amounts were
outstanding under the seasonal revolving loan and
$0.5 million of letters of credit were outstanding.
We acquired Platte Valley Fuel Ethanol, LLC in April 2006. Prior
to this acquisition, Platte Valley Fuel Ethanol had entered into
a senior secured credit facility with First National Bank of
Omaha. In August 2006, Platte Valley entered into a credit
facility with First National Bank of Omaha to finance the
expansion project. On February 7, 2007, Platte Valley used
funds from the AgStar credit facility to prepay all the
outstanding debt with First National Bank of Omaha in the
aggregate amount of $36.8 million. In connection with the
refinancing, Platte Valley incurred and expensed a prepayment
penalty of $0.7 million and $0.7 million of debt
financing costs. Platte Valley used a portion of the proceeds of
these credit facilities to make a one-time distribution to us
for the portion of the expansion project costs that were paid
with our additional equity contributions in excess of the 40%
that we were required to pay under our loan agreement.
On October 31, 2003, Platte Valley entered into a
redevelopment contract with the Community Redevelopment
Authority of the City of Central City, Nebraska, pursuant to
which the city issued revenue bonds. Platte Valley received a
portion of the bond proceeds in the form of grants to be used to
fund, in part, the development and construction of the original
Platte Valley plant. Platte Valley is obligated to repay the
bonds with semiannual interest and principal payments at fixed
interest rates ranging from 6.25% to 7.25%. As of
September 30, 2007, there was an outstanding balance of
$3.4 million on the bonds.
Woodbury
In November 2006, the Woodbury construction loan was converted
to a term loan a revolving loan and a seasonal revolving loan.
As of September 30, 2007, $27.0 million was
outstanding under the term loan and $8.0 million was
outstanding under the revolving term loan. In addition, Woodbury
has a $3.5 million seasonal revolving loan that is
available for working capital needs, which allows for
$3.0 million to be used for letters of credit. As of
September 30, 2007, no amount was outstanding under
Woodburys seasonal revolving loan and $0.9 million of
letters of credit were outstanding.
In November 2005, Woodbury entered into a senior secured credit
facility with AgStar, as administrative agent and as a lender,
and a group of other lenders to finance the development and
construction of our Woodbury ethanol plant.
In May 2006, Woodbury entered into two loan agreements with the
State of Michigans Department of Transportation, to
provide Woodbury with financial assistance in the form of a loan
to perform railroad infrastructure improvements. As of
September 30, 2007, the outstanding balance under this loan
agreement was $0.8 million.
Dyersville
On February 7, 2007, Dyersville entered into a senior
secured credit facility construction loan with AgStar, as
administrative agent and as a lender, and a group of other
lenders for our Dyersville, Iowa plant. This senior secured
credit facility is structured as a construction loan not to
exceed $105.1 million with $5.0 million available for
letters of credit. This construction loan will provide funds
necessary to finance up to 60% of the construction costs and we
must provide the necessary funds to provide for 40% of the
construction
33
costs before funds are available under the credit facility. In
addition, a $10.0 million seasonal revolving credit
facility will be available to Dyersville upon the conversion of
the construction loan to a term loan. As of September 30,
2007, we had outstanding borrowings of $8.9 million and no
outstanding letters of credit for our Dyersville construction
project.
Hankinson
On February 7, 2007, Hankinson entered into a senior
secured credit facility with AgStar, as administrative agent and
as a lender, and a group of other lenders. This senior secured
credit facility is structured as a construction loan not to
exceed $95.1 million with $5.0 million available for
letters of credit. This construction loan will provide funds
necessary to finance up to 60% of construction costs. We must
provide the necessary funds to provide for 40% of the
construction costs before funds are available under this credit
facility. In addition, a $10.0 million seasonal revolving
credit facility will be available to Hankinson upon the
conversion of the construction loan to a term loan. As of
September 30, 2007, we had $34.7 million of
outstanding borrowings and $4.3 million of outstanding
letters of credit for our Hankinson construction project.
Janesville
On February 7, 2007, Janesville entered into a senior
secured credit facility with AgStar, as administrative agent and
as a lender, and a group of other lenders for our Janesville,
Minnesota plant. This senior secured credit facility is
structured as a construction loan not to exceed
$90.3 million with $5.0 million available for letters
of credit. This construction loan will provide funds necessary
to finance up to 60% of the construction costs and we must
provide the necessary funds to provide for 40% of the
construction costs before funds are available under the credit
facility. In addition, a $10.0 million seasonal revolving
credit facility will be available to Janesville upon the
conversion of the construction loan to a term loan. As of
September 30, 2007, we had no outstanding borrowings and no
outstanding letters of credit for our Janesville construction
project.
Marion
On August 29, 2007, we acquired Millennium Ethanol, LLC, a
development stage company, and subsequently changed its name to
US Bio Marion, LLC (Marion). Marion is constructing an ethanol
plant near Marion, South Dakota (see Note 6 for more
detail). Marions senior construction loan with Dougherty
Funding LLC (Dougherty) has a total commitment of
$90.0 million, and a revolving loan of up to
$7.0 million. The terms of the senior construction loan
commitment allow advances to be made through May 31, 2008.
After conversion of the senior construction loan to a term loan,
payments will be based on monthly amortized payments of
principal and interest sufficient to amortize the remaining
unpaid principal balance to a maturity date of March 31,
2013. The senior construction loan is secured by substantially
all of the assets of Marion. The revolving line of credit is
secured by Marions inventory and accounts receivable and
expires on May 28, 2009. Marion also has availability of
$7.3 million under a letters of credit agreement with First
Bank & Trust, a South Dakota state bank, to be issued
on behalf of Marion to satisfy the requirements of certain
utility service providers to secure Marions contractual
obligation to them under certain agreements with these service
utility providers. As of September 30, 2007, Marion had
outstanding borrowings under its construction loan of
$51.9 million, no amounts outstanding on its revolving
credit facility and outstanding letters of credit of
$1.1 million.
As of September 30, 2007, our subsidiaries were in
compliance with all applicable financial covenants contained in
the loan agreements evidencing each of the credit facilities
discussed above.
34
The total outstanding borrowings and total available capacity
under our current credit facilities as of September 30,
2007 were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Plants in Operation
|
|
|
Plants under Construction
|
|
|
|
|
|
|
Albert
|
|
|
|
|
|
Platte
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
City
|
|
|
Ord
|
|
|
Valley
|
|
|
Woodbury
|
|
|
Dyersville
|
|
|
Hankinson
|
|
|
Janesville
|
|
|
Marion
|
|
|
Total
|
|
|
|
(Dollars in thousands)
|
|
|
Construction
loans:
(2)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Senior secured facilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total capacity
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
105,100
|
|
|
$
|
95,100
|
|
|
$
|
90,300
|
|
|
$
|
97,300
|
|
|
$
|
387,800
|
|
Letters of credit
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4,324
|
|
|
|
|
|
|
|
1,077
|
|
|
|
5,401
|
|
Outstanding borrowings
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
8,894
|
|
|
|
34,744
|
|
|
|
|
|
|
|
51,868
|
|
|
|
95,506
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total available capacity
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
96,206
|
|
|
|
56,032
|
|
|
|
90,300
|
|
|
|
44,355
|
|
|
|
286,893
|
|
Term
loans:
(1)(3)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Seasonal revolving loans:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total capacity
|
|
|
6,500
|
|
|
|
10,000
|
|
|
|
10,000
|
|
|
|
3,500
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
7,000
|
|
|
|
37,000
|
|
Letters of credit
|
|
|
2,717
|
|
|
|
|
|
|
|
480
|
|
|
|
855
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4,052
|
|
Outstanding borrowings
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total available capacity
|
|
|
3,783
|
|
|
|
10,000
|
|
|
|
9,520
|
|
|
|
2,645
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
7,000
|
|
|
|
32,948
|
|
Senior secured facilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total capacity
|
|
|
64,577
|
|
|
|
34,875
|
|
|
|
65,857
|
|
|
|
26,959
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
192,268
|
|
Outstanding borrowings
|
|
|
64,577
|
|
|
|
34,875
|
|
|
|
65,857
|
|
|
|
26,959
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
192,268
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total available capacity
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revolving term loans:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total capacity
|
|
|
12,638
|
|
|
|
11,625
|
|
|
|
22,500
|
|
|
|
8,000
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
54,763
|
|
Outstanding borrowings
|
|
|
12,638
|
|
|
|
11,625
|
|
|
|
22,500
|
|
|
|
8,000
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
54,763
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total available capacity
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total capacity
|
|
|
83,715
|
|
|
|
56,500
|
|
|
|
98,357
|
|
|
|
38,459
|
|
|
|
105,100
|
|
|
|
95,100
|
|
|
|
90,300
|
|
|
|
104,300
|
|
|
|
671,831
|
|
Letters of credit
|
|
|
2,717
|
|
|
|
|
|
|
|
480
|
|
|
|
855
|
|
|
|
|
|
|
|
4,324
|
|
|
|
|
|
|
|
1,077
|
|
|
|
9,453
|
|
Outstanding borrowings
|
|
|
77,215
|
|
|
|
46,500
|
|
|
|
88,357
|
|
|
|
34,959
|
|
|
|
8,894
|
|
|
|
34,744
|
|
|
|
|
|
|
|
51,868
|
|
|
|
342,537
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total available capacity
|
|
$
|
3,783
|
|
|
$
|
10,000
|
|
|
$
|
9,520
|
|
|
$
|
2,645
|
|
|
$
|
96,206
|
|
|
$
|
56,032
|
|
|
$
|
90,300
|
|
|
$
|
51,355
|
|
|
$
|
319,841
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Economic development loans/revenue bonds
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
4,526
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total debt
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
347,063
(4
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
|
The construction loans convert to term loans 120 days after
substantial completion of each construction project. Ords
construction loan converted in September 2007.
|
|
(2)
|
|
Each of the Dyersville, Hankinson and Janesville construction
projects can secure up to $5.0 million in letters of
credit. The Marion construction loan has up to $7.3 million
reserved for letters of credit.
|
|
(3)
|
|
Albert City and Woodbury can secure up to $3.0 million in
letters of credit against their seasonal revolving loans. Platte
Valley and Ord each can secure up to $5.0 million in
letters of credit against their seasonal revolving loans.
|
|
(4)
|
|
Represents the total debt as recorded on our balance sheet and
is comprised of outstanding borrowings under all of our existing
credit facilities of $342.5 million plus the outstanding
balance on the economic development loans and revenue bonds of
$4.5 million.
|
As of September 30, 2007, the current portion of long-term
debt was $15.8 million.
We believe that our cash and cash equivalents, cash from
operations and borrowings under our existing credit arrangements
will be sufficient to meet our anticipated future operational
expenses. As discussed above,
35
additional financing will be required to fund our 50% share of
Grinnells construction costs and other additional ethanol
plants beyond those currently under construction.
OFF-BALANCE
SHEET ARRANGEMENTS
We do not have any off-balance sheet arrangements that have or
are reasonably likely to have a material current or future
effect on our financial position, changes in financial position,
revenues or expenses, results of operations, liquidity, capital
expenditures or capital resources.
CONTRACTUAL
OBLIGATIONS
There have been no material changes during the periods covered
by this Quarterly Report on
Form 10-Q,
outside of our ordinary course of business, to the contractual
obligations specified in the table of contractual obligations in
the section Managements Discussion and Analysis of
Financial Condition and Results of Operation included in
our Fiscal 2006 Annual Report on
Form 10-K,
except as described below.
On February 7, 2007, we entered into new senior secured
credit facilities with AgStar and on August 29, 2007 we
acquired Millennium, which had previously entered into various
credit facilities. See Item 2 under the Credit
Arrangements section for more detail.
CRITICAL
ACCOUNTING ESTIMATES
Our Critical Accounting Estimates are presented in our Fiscal
2006 Annual Report on
Form 10-K.
There have been no changes to these estimates during the nine
months ended September 30, 2007, except as discussed below.
During the first quarter of 2007, we began entering into
exchange-traded energy futures contracts to manage our risk on
ethanol sales. During the second quarter of 2007, we began
entering into over-the-counter financial instruments to manage
our risk on corn purchases. We account for derivative financial
instruments at fair value in the condensed consolidated
financial statements with changes in fair value being recorded
in cost of goods sold.
CAUTIONARY
STATEMENT FOR PURPOSES OF THE SAFE HARBOR PROVISIONS OF THE
PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995
This Quarterly Report on
Form 10-Q
contains forward-looking statements that are not statements of
historical fact and may involve a number of risks and
uncertainties. These statements relate to analyses and other
information that are based on forecasts of future results and
estimates of amounts not yet determinable. These statements also
relate to our future prospects, developments and business
strategies.
We have used the words anticipate,
believe, continue, ongoing,
estimate, expect, intend,
may, plan, potential,
predict, project and similar words or
phrases, including references to assumptions, to identify
forward-looking statements in this Quarterly Report on
Form 10-Q,
but the absence of these words does not necessarily mean that a
statement is not forward-looking. These forward-looking
statements are made based on our expectations and beliefs
concerning future events affecting us and are subject to
uncertainties and factors relating to our operations and
business environment, all of which are difficult to predict and
many of which are beyond our control, that could cause our
actual results to differ materially from those matters expressed
in or implied by these forward-looking statements.
We do not undertake any responsibility to release publicly any
revisions to these forward-looking statements to take into
account events or circumstances that occur after the date of
this Quarterly Report on
Form 10-Q.
Additionally, we do not undertake any responsibility to update
you on the occurrence of any unanticipated events which may
cause actual results to differ from those expressed or implied
by the forward-looking statements contained in this Quarterly
Report on
Form 10-Q.
36
Important factors that could cause actual results to differ
materially from our expectations are disclosed under Risk
factors below and elsewhere in our Annual Report on
Form 10-K
for the fiscal year ended December 31, 2006. Such factors
include, among others:
|
|
|
|
|
the volatility and uncertainty of commodity prices;
|
|
|
|
changes in ethanol supply and demand;
|
|
|
|
development of infrastructure related to the sale and
distribution of ethanol;
|
|
|
|
changes in current legislation or regulations that affect
ethanol supply and demand or governmental subsidies;
|
|
|
|
concerns about the efficiency of corn-based ethanol;
|
|
|
|
our ability to compete effectively in the industry;
|
|
|
|
our limited operating history and history of operating losses;
|
|
|
|
our ability to successfully locate and integrate future
acquisitions;
|
|
|
|
our ability to implement our expansion strategy as planned or at
all;
|
|
|
|
the results of our hedging transactions;
|
|
|
|
operational difficulties at our ethanol plants;
|
|
|
|
the adverse effect of environmental, health and safety laws,
regulations and liabilities, including potentially significant
changes in environmental regulations;
|
|
|
|
our less than 100% ownership of and control over certain assets
used in our business;
|
|
|
|
disruptions to infrastructure or in the supply of raw materials;
|
|
|
|
the limited use of our historical financial information in
evaluating our performances;
|
|
|
|
the division of our managements time and energy among our
different ethanol plants;
|
|
|
|
competition for qualified personnel in the ethanol industry;
|
|
|
|
our ability to keep pace with technological advances;
|
|
|
|
our significant amount of debt and the restrictive covenants in
our debt financing agreements;
|
|
|
|
the material weakness and reportable conditions identified in
our internal controls;
|
|
|
|
we are subject to financial reporting and other requirements for
which we may not be adequately prepared;
|
|
|
|
our ability to continue to provide services to competing
third-party producers;
|
|
|
|
our status as a holding company; and
|
|
|
|
certain of our shareholders could exert significant influence
over us.
|
|
|
ITEM 3.
|
QUANTITATIVE
AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
|
We consider market risk to be the potential loss arising from
adverse changes in market rates and prices.
We manage our exposure to various risks according to risk
management guidelines that were approved by our management. We
regularly monitor compliance with these risk management
guidelines.
In our effort to reduce price risk caused by market fluctuation
in the prices of commodities and interest rates, we may enter
into exchange traded commodities futures, options, cash
contracts and over-the-counter instruments. To manage our
exposure to interest rate risk, we may also enter into certain
instruments, including interest rate swaps and similar hedging
techniques. These hedging arrangements could expose us to
potential
37
gains or losses, which would impact our earnings. On cash
fixed-price or over-the-counter contracts there is a risk of
financial loss in situations where the other party to the
hedging contract defaults on its contract.
We account for derivative instruments in accordance with the
Financial Accounting Standards Board (FASB) Statement of
Financial Accounting Standards (SFAS) No. 133,
Accounting for Derivative Instruments and Hedging
Activities (SFAS 133). These futures contracts are
accounted for as derivative financial instruments at fair value
in the financial statements with the changes in fair value being
recorded in cost of goods sold. Under SFAS 133, the
accounting for changes in the fair value of a derivative depends
upon whether it has been designated as an accounting hedging
relationship and, further, on the type of hedging relationship.
To qualify for designation as an accounting hedging
relationship, specific criteria must be met and appropriate
documentation maintained. We had no derivative instruments that
qualified under these rules as designated accounting hedges for
any of the periods reported in this Quarterly Report on
Form 10-Q
and, as such, have not recorded any transactions under these
rules.
We extend credit to our customers in the ordinary course of
business in the form of trade accounts receivable. We have a
significant concentration of accounts receivable with Provista,
our ethanol marketing joint venture, to which we sell all of our
ethanol. As of September 30, 2007, accounts receivable from
Provista accounted for 59% of our total accounts receivable. We
routinely assess the quality of our accounts receivable and, as
a result of that assessment, believe that our trade accounts
receivable credit risk exposure is limited.
We are subject to significant market risk with respect to the
price of ethanol, and the price and availability of corn and
natural gas, the principal raw materials we use to produce
ethanol and distillers grains. In general, ethanol prices are
influenced by the supply and demand for gasoline, the
availability of substitutes and the effect of laws and
regulations. In addition, our business is highly sensitive to
corn prices and we generally cannot pass on increases in corn
prices to our customers. High corn prices, and/or, high natural
gas prices in relation to the price of ethanol, could have a
material adverse effect on our results of operations.
Our gross margins depend principally on the spread between
ethanol and corn prices. During the five-year period from 2002
to 2006, ethanol prices (based on price data from Bloomberg,
L.P., or Bloomberg) have ranged from a low of $0.91 per gallon
to a high of $3.95 per gallon, averaging $1.65 per gallon during
this period. On September 28, 2007, the Chicago spot price
per gallon of ethanol was $1.54, whereas on September 29,
2006, the Chicago spot price per gallon of ethanol was $1.75.
During most of 2006, the spread between ethanol and corn prices
was at historically high levels, driven largely by the increased
demand for ethanol used as a fuel additive and historically low
corn prices. However, in 2007, the price of ethanol has declined
from the high levels that were prevalent in the first three
quarters of 2006 and the cost of corn has risen. The spread
between the price of a gallon of ethanol and the cost of the
amount of corn required to produce a gallon of ethanol will
continue to fluctuate. A sustained narrow spread or any further
reduction in the spread between ethanol and corn prices, whether
as a result of sustained high or increased corn prices or
sustained low or decreased ethanol prices, could have a material
adverse effect on our business, results of operations and
financial condition.
We purchase significant amounts of corn to support the needs of
our production plants. Higher corn costs result in lower profit
margins and therefore represent unfavorable market conditions.
We may not be able to pass along increased corn costs to our
ethanol customers. The availability and price of corn is subject
to wide fluctuations due to unpredictable factors such as
weather conditions (including droughts), farmers planting
decisions, governmental policies with respect to agriculture and
international trade and global demand and supply. Over the
eleven-year period from 1996 through 2006, corn prices (based on
the Chicago Board of Trade (CBOT)) daily futures data have
ranged from a low of $1.75 per bushel in 2000 to a high of $5.48
per bushel in 1996, with prices averaging $2.49 per bushel
during this period. On September 28, 2007, the price of
corn was $3.73 per bushel and on September 29, 2006, the
CBOT price of corn was $2.62 per bushel.
We rely upon third parties for our supply of natural gas, which
we consume to manufacture ethanol. The prices for and
availability of natural gas are subject to volatile market
conditions. The fluctuations in natural gas prices over the
five-year period from 2002 through 2006, based on New York
Mercantile Exchange, Inc., or NYMEX, daily futures data, has
ranged from a low of $1.91 per Million British Thermal Units, or
MMBTU, in 2002 to a high of $15.38 per MMBTU in 2005, averaging
$6.21 per MMBTU during this period. On September 28, 2007,
the NYMEX price of natural gas was $6.87 per MMBTU, and on
September 29,
38
2006, the NYMEX price of natural gas was $5.62 per MMBTU. These
market conditions often are affected by factors beyond our
control such as weather conditions (including hurricanes),
overall economic conditions and foreign and domestic
governmental regulation and relations.
We have prepared a sensitivity analysis to our exposure to
market risk with respect to corn and natural gas requirements
along with our ethanol and distillers grains sales, based on
average prices for the nine months ended September 30,
2007. We based our analysis on the most recent nine months of
operations due to the rapid expansion of our business. A
hypothetical 10% change in the average price of the commodities
listed below would result in the following change in annual
gross profit:
|
|
|
|
|
|
|
|
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|
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Nine Months Ended September 30, 2007
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|
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Hypothetical
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Percentage
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|
|
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Change in
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Change in
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Change in
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Units
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Price
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Gross Profit
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Gross Profit
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(In millions)
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(Dollars in millions)
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Corn
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69.8
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bushels
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10
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%
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$
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25.3
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|
|
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103
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%
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Ethanol
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|
|
200.0
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|
|
gallons
|
|
|
10
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%
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$
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37.2
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|
|
150
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%
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Distillers Grains
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|
0.92
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tons
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|
|
10
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%
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$
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5.0
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|
|
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21
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%
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Natural Gas
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|
|
5.1
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MMBTU
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|
|
10
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%
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$
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3.3
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|
|
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13
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%
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|
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ITEM 4.
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CONTROLS
AND PROCEDURES
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DISCLOSURE
CONTROLS AND PROCEDURES
Our management, with the participation of our Chief Executive
Officer and Chief Financial Officer, has evaluated the
effectiveness of our disclosure controls and
procedures (as defined in
Rules 13a-15(e)
and
15d-15(e)
under the Securities Exchange Act of 1934, as amended (the
Exchange Act)) as of the end of the period covered by this
report. Based on that evaluation, our Chief Executive Officer
and Chief Financial Officer have concluded that, as of the end
of such period, our disclosure controls and procedures were
effective.
CHANGES
IN INTERNAL CONTROLS OVER FINANCIAL REPORTING
We are currently undergoing a comprehensive effort in
preparation for compliance with Section 404 of the
Sarbanes-Oxley Act of 2002. This effort, under the direction of
senior management, includes documenting process narratives and
testing of general computer and business process controls. We
continue to remediate identified deficiencies and perform
on-going tests relating to internal controls over financial
reporting. We have also completed a risk assessment, established
a reporting methodology, and formalized an internal audit plan
that has been reviewed by the Audit Committee.
Except as described above, there has been no change in our
internal control over financial reporting (as defined in
Rules 13a-15(f)
and
15d-15(f)
under the Exchange Act) that occurred in the quarter ended
September 30, 2007, that has materially affected, or is
reasonably likely to materially affect, our internal control
over financial reporting.
PART II.
OTHER INFORMATION
RISKS
RELATED TO OUR BUSINESS AND OPERATIONS
Our
business is highly dependent on commodity prices, which are
subject to significant volatility and uncertainty, so our
results could fluctuate significantly.
We generally do not have long-term, fixed price contracts for
the purchase of corn and natural gas, our principal inputs, or
for the sale of ethanol, our principal product. Therefore, our
results of operations, financial position and business outlook
are substantially dependent on commodity prices, especially
prices for corn,
39
natural gas, ethanol and unleaded gasoline. Prices for these
commodities are generally subject to significant volatility and
uncertainty. As a result, our future results may fluctuate
substantially, and we may experience periods of declining prices
for our products and increasing costs for our raw materials,
which could result in operating losses. We may attempt to offset
a portion of the effects of such fluctuations by entering into
forward contracts to supply ethanol or to purchase corn, natural
gas or other items or by engaging in transactions involving
exchange-traded futures contracts, but these activities involve
substantial costs and substantial risks and may be ineffective
to mitigate these fluctuations.
The
spread between ethanol and corn prices can vary significantly
and during 2006 was at historically high levels.
Our gross margins depend principally on the spread between
ethanol and corn prices. During the five-year period from 2002
to 2006, ethanol prices (based on price data from Bloomberg,
L.P., or Bloomberg) have ranged from a low of $0.91 per gallon
to a high of $3.95 per gallon, averaging $1.65 per gallon during
this period. During the first three quarters of 2006, the spread
between ethanol and corn prices was at historically high levels,
driven in large part by high oil prices and historically low
corn prices. Since the end of 2006, however, the price of
ethanol has been declining and the cost of corn has been rising.
On September 28, 2007, the Chicago spot price per gallon of
ethanol was $1.54, whereas on September 29, 2006, the
Chicago spot price per gallon of ethanol was $1.75. Over the
same period, corn prices (based on Chicago Board of Trade, or
CBOT, daily futures data) have risen from $3.73 per bushel on
September 28, 2007, from $2.62 per bushel on
September 29, 2006. The spread between the price of a
gallon of ethanol and the cost of the amount of corn required to
produce a gallon of ethanol will likely continue to fluctuate. A
sustained narrow spread or any further reduction in the spread
between ethanol and corn prices, whether as a result of
sustained high or increased corn prices or sustained low or
decreased ethanol prices, could have a material adverse effect
on our business, results of operations and financial condition.
Our
business is highly sensitive to corn prices, and we generally
cannot pass on increases in corn prices to our
customers.
Corn is the principal raw material we use to produce ethanol and
distillers grains. Because ethanol competes with fuels that are
not corn-based, we generally are unable to pass along increased
corn costs to our customers, and accordingly, rising corn prices
tend to produce lower profit margins. At certain levels, corn
prices would make ethanol uneconomical to use in fuel markets.
The price of corn is influenced by weather conditions (including
droughts) and other factors affecting crop yields, farmer
planting decisions and general economic, market and regulatory
factors, including government policies and subsidies with
respect to agriculture and international trade, and global and
local supply and demand. Any decline in the corn harvest, caused
by farmer planting decisions or otherwise, could cause corn
prices to increase and negatively impact our gross margins. The
price of corn has fluctuated significantly in the past and may
fluctuate significantly in the future. For example, over the
eleven-year period from 1996 through 2006, corn prices (based on
CBOT daily futures data) have ranged from a low of $1.75 per
bushel in 2000 to a high of $5.48 per bushel in 1996, with
prices averaging $2.45 per bushel during this period. During the
third quarter of 2007, corn prices were at substantially higher
levels than both the eleven-year average and average corn prices
during 2006, ranging from a low of $3.10 per bushel to a high of
$3.87 per bushel, with prices averaging $3.87 per bushel.
In addition, increasing domestic ethanol capacity could boost
demand for corn and result in increased corn prices. In 2006,
corn bought by ethanol plants represented approximately 18% of
the total corn supply for that year according to results
reported by the National Corn Growers Association, and this
percentage is expected to increase as additional ethanol
capacity comes online, rising to more than 30% of the total corn
supply by
2009/2010
according to the United States Department of Agriculture or
USDA. At a more local level, the price we pay for corn at any of
our plants could also increase if another ethanol plant were
built in the same general vicinity or if we expand the plant.
We may also have difficulty from time to time in purchasing corn
on satisfactory terms due to supply shortages. Any supply
shortage could require us to suspend operations until corn
becomes available on
40
satisfactory terms. Suspension of operations could have a
material adverse effect on our business, results of operations
and financial condition.
The
market for natural gas is subject to market conditions that
create uncertainty in the price and availability of the natural
gas that we utilize in the ethanol manufacturing
process.
We rely upon third-parties for our supply of natural gas which
is consumed as fuel in the manufacture of ethanol. The prices
for and availability of natural gas are subject to volatile
market conditions. The fluctuations in natural gas prices over
the five-year period from 2002 through 2006, based on New York
Mercantile Exchange, Inc., or NYMEX, daily futures data, have
ranged from a low of $1.91 per MMBTU, in 2002 to a high of
$15.38 per MMBTU in 2005, averaging $6.21 per MMBTU during this
period. On September 28, 2007, the NYMEX price of natural
gas was $6.87 per MMBTU, and on September 29, 2006, the
NYMEX price of natural gas was $5.62 per MMBTU. These market
conditions often are affected by factors beyond our control such
as weather conditions (including hurricanes), overall economic
conditions and foreign and domestic governmental regulation and
relations. Significant disruptions in the supply of natural gas
could impair our ability to manufacture ethanol for our
customers. Further, increases in natural gas prices could have a
material adverse effect on our business, results of operations
and financial condition.
Fluctuations
in the selling price and production cost of gasoline may reduce
our profit margins.
Ethanol is marketed both as a fuel additive to reduce vehicle
emissions from gasoline and as an octane enhancer to improve the
octane rating of gasoline with which it is blended. As a result,
ethanol prices are influenced by the supply and demand for
gasoline and our business, future results of operations and
financial condition may be materially adversely affected if
gasoline demand or price decreases.
The
price of distillers grains is affected by the price of other
commodity products, such as soybeans, and decreases in the price
of these commodities could decrease the price of distillers
grains.
Distillers grains compete with other protein-based animal feed
products. The price of distillers grains may decrease when the
price of competing feed products decrease. The prices of
competing animal feed products are based in part on the prices
of the commodities from which they are derived. Downward
pressure on commodity prices, such as soybeans, will generally
cause the price of competing animal feed products to decline,
resulting in downward pressure on the price of distillers
grains. Because the price of distillers grains is not tied to
production costs, decreases in the price of distillers grains
will result in our generating less revenue and lower profit
margins.
Our
business is subject to seasonal fluctuations.
Our operating results are influenced by seasonal fluctuations in
the price of our primary operating inputs, corn and natural gas,
and the price of our primary product, ethanol. In recent years,
the spot price of corn tended to rise during the spring planting
season in May and June and tended to decrease during the fall
harvest in October and November. The price for natural gas
however, tends to move opposite of corn and tends to be lower in
the spring and summer and higher in the fall and winter. In
addition, our ethanol prices are substantially correlated with
the price of unleaded gasoline. The price of unleaded gasoline
tends to rise during the summer. Given our limited history, we
do not know yet how these seasonal fluctuations will affect our
results over time.
As more
ethanol plants are built, ethanol production will increase and,
if demand does not sufficiently increase, the price of ethanol
and distillers grains may decrease.
According to the RFA, domestic ethanol production capacity has
increased steadily from 1.7 billion gallons per year in
January of 1999 to 6.2 billion gallons per year in
September 2007. In addition, there is a significant amount of
production capacity being added to the ethanol industry.
According to the RFA, as of September 2007, approximately
6.4 billion gallons per year of production capacity, an
increase of 104% over current production levels, is currently
under construction at 85 new and existing plant. This capacity
is being
41
added to address anticipated increases in demand. However,
demand for ethanol may not increase as quickly as expected or to
a level that exceeds supply, or at all. Recently, several
ethanol companies have announced the postponement of ethanol
plants under construction due, in part, to concerns about excess
production capacity in the ethanol industry. If the ethanol
industry has excess production capacity, it could have a
material adverse effect on our business, results of operations
and financial condition.
Excess ethanol production capacity also may result from
decreases in the demand for ethanol or increased imported
supply, which could result from a number of factors, including
regulatory developments and reduced gasoline consumption in the
U.S. Reduced gasoline consumption could occur as a result
of increased prices for gasoline or crude oil, which could cause
businesses and consumers to reduce driving or acquire vehicles
with more favorable gasoline mileage, or as a result of
technological advances, such as the commercialization of engines
utilizing hydrogen fuel-cells, which could supplant
gasoline-powered engines. There are a number of governmental
initiatives designed to reduce gasoline consumption, including
tax credits for hybrid vehicles and consumer education programs.
In addition, because ethanol production produces distillers
grains as a co-product, increased ethanol production will also
lead to increased supplies of distillers grains. An increase in
the supply of distillers grains, without corresponding increases
in demand, could lead to lower prices or an inability to sell
our distillers grains production. A decline in the price of
distillers grains or the distillers grains market generally
could have a material adverse effect on our business, results of
operations and financial condition.
Growth in
the sale and distribution of ethanol is dependent on the changes
in and expansion of related infrastructure which may not occur
on a timely basis, or at all, and our operations could be
adversely affected by infrastructure disruptions.
Substantial development of infrastructure by persons and
entities outside our control will be required for our
operations, and the ethanol industry generally, to grow. Areas
requiring expansion include, but are not limited to:
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|
|
additional rail capacity;
|
|
|
|
additional storage facilities for ethanol;
|
|
|
|
increases in truck fleets capable of transporting ethanol within
localized markets;
|
|
|
|
expansion of refining and blending facilities to handle ethanol;
|
|
|
|
growth in service stations equipped to handle ethanol
fuels; and
|
|
|
|
growth in the fleet of flexible fuel vehicles capable of using
E85 fuel.
|
The rapid expansion of the ethanol industry currently underway
compounds the issues presented by the need to develop and expand
ethanol related infrastructure, as the lack of infrastructure
prevents the use of ethanol in certain areas where there might
otherwise be demand and results in excess ethanol supply in
areas with more established ethanol infrastructure, depressing
ethanol prices in those areas. Substantial investments required
for these infrastructure changes and expansions may not be made
or may not be made on a timely basis. Any delay or failure in
making the changes in or expansion of infrastructure could hurt
the demand or prices for our products, impede our delivery of
products, impose additional costs on us or otherwise have a
material adverse effect on our business, results of operations
or financial condition. Our business is dependent on the
continuing availability of infrastructure and any infrastructure
disruptions could have a material adverse effect on our
business, results of operations and financial condition.
42
The use
of and demand for ethanol and its supply are highly dependent on
various federal and state legislation and regulation, and any
changes in legislation or regulation could cause the demand for
ethanol to decline or its supply to increase, which could have a
material adverse effect on our business, results of operations
and financial condition.
Various federal and state laws, regulations and programs have
led to increased use of ethanol in fuel. For example, certain
laws, regulations and programs provide economic incentives to
ethanol producers and users. Further, tariffs generally apply to
the import of ethanol from other countries. These laws,
regulations and programs are constantly changing. Federal and
state legislators and environmental regulators could adopt or
modify laws, regulations or programs that could adversely affect
the use of ethanol. In addition, certain state legislatures
oppose the use of ethanol because they must ship ethanol in from
ethanol plants, which are typically located in corn-producing
states, which could significantly increase gasoline prices in
the state.
The
elimination or significant reduction in the federal ethanol tax
incentive or the elimination or expiration of other federal or
state incentive programs could have a material adverse effect on
our business, results of operations and financial
condition.
The cost of producing ethanol has historically been
significantly higher than the market price of gasoline. The
production of ethanol is made significantly more competitive
with regular gasoline because of federal tax incentives. Before
January 1, 2005, the federal excise tax incentive program
allowed gasoline distributors who blended ethanol with gasoline
to receive a federal excise tax rate reduction for each blended
gallon they sold. If the fuel was blended with 10% ethanol, the
refiner/marketer paid $0.052 per gallon less tax, which equated
to an incentive of $0.52 per gallon of ethanol. The $0.52 per
gallon incentive for ethanol was reduced to $0.51 per gallon in
2005 and was subsequently extended until 2010. The federal
ethanol tax incentives may not be renewed in 2010 or they may be
renewed on different terms. In addition, the federal ethanol tax
incentives, as well as other federal and state programs
benefiting ethanol (such as tariffs on imported ethanol),
generally are subject to U.S. government obligations under
international trade agreements, including those under the World
Trade Organization Agreement on Subsidies and Countervailing
Measures, and might be the subject of challenges thereunder, in
whole or in part. We may also receive benefits from other
federal and state incentive programs. For example, historically,
our Platte Valley plant has received incentive payments to
produce ethanol from the USDA under its Commodity Credit
Corporation Bioenergy Program and from the State of Nebraska
under its motor vehicle fuel tax credit program. Under the State
of Nebraska program, Platte Valley received payments of
approximately $2.8 million in 2007 and 2006. The USDA
program expired on June 30, 2006, and the State of Nebraska
program is set to expire in 2012. The elimination or significant
reduction in the federal ethanol tax incentive or other programs
benefiting ethanol could have a material adverse effect on our
business, results of operations and financial condition.
The
effect of the Renewable Fuels Standard, or RFS, in the Energy
Policy Act of 2005, or Energy Act, on the ethanol industry is
uncertain.
The use of fuel oxygenates, including ethanol, was mandated
through regulation, and much of the forecasted growth in demand
for ethanol was expected to result from additional mandated use
of oxygenates. Most of this growth was projected to occur in the
next few years as the remaining markets switch from MTBE to
ethanol. The Energy Act, however, eliminated the mandated use of
oxygenates and instead established minimum nationwide levels of
renewable fuels (ethanol, biodiesel or any other liquid fuel
produced from biomass or biogas) to be included in gasoline.
Because biodiesel and other renewable fuels in addition to
ethanol are counted toward the minimum usage requirements of the
RFS, the elimination of the oxygenate requirement for
reformulated gasoline may result in a decline in ethanol
consumption, which in turn could have a material adverse effect
on our business, results of operations and financial condition.
The Energy Act also included provisions for trading of credits
for use of renewable fuels and authorized potential reductions
in the RFS minimum by action of a governmental administrator. In
addition, the rules for implementation of the RFS and the Energy
Act are still under development.
The Energy Act did not include MTBE liability protection sought
by refiners, and, in light of the risks of environmental
litigation, many ethanol producers have anticipated that this
will result in accelerated removal
43
of MTBE and increased demand for ethanol. Refineries may use
other possible replacement additives, such as iso-octane,
iso-octene or alkylate. Accordingly, the actual demand for
ethanol may increase at a lower rate than production for
anticipated demand, resulting in excess production capacity in
our industry, which could materially adversely affect our
business, results of operations and financial condition.
Tariffs
effectively limit the importation of ethanol into the U.S., and
their reduction or elimination could undermine the ethanol
industry in the U.S.
Imported ethanol is generally subject to a $0.54 per gallon
tariff that was designed to offset the $0.51 per gallon ethanol
incentive available under the federal excise tax incentive
program for refineries that blend ethanol in their fuel. There
is, however, a special exemption from this tariff for ethanol
imported from 24 countries in Central America and the Caribbean
Islands, which is limited to a total of 7% of U.S. ethanol
production per year. Imports from the exempted countries may
increase as a result of new plants in development. Since
production costs for ethanol in these countries are
significantly less than what they are in the U.S., the duty-free
import of ethanol through the countries exempted from the tariff
may negatively affect the demand for domestic ethanol and the
price at which we sell our ethanol.
We do not know the extent to which the volume of imports would
increase or the effect on U.S. prices for ethanol if the
tariff is not renewed beyond its current expiration date in
January 2009. Any changes in the tariff or exemption from the
tariff could have a material adverse effect on our business,
results of operations and financial condition.
Waivers
of the RFS minimum levels of renewable fuels included in
gasoline could have a material adverse effect on our business,
results of operations and financial condition.
Under the Energy Policy Act of 2005, the U.S. Department of
Energy, in consultation with the Secretary of Agriculture and
the Secretary of Energy, may waive the renewable fuels mandate
with respect to one or more states if the Administrator of the
U.S. EPA, determines that implementing the requirements
would severely harm the economy or the environment of a state, a
region or the U.S., or that there is inadequate supply to meet
the requirement. Any waiver of the RFS with respect to one or
more states could adversely affect demand for ethanol and could
have a material adverse effect on our business, results of
operations and financial condition.
Various
studies have criticized the efficiency of ethanol, in general,
and corn-based ethanol in particular, which could lead to the
reduction or repeal of incentives and tariffs that promote the
use and domestic production of ethanol or otherwise negatively
impact public perception and acceptance of ethanol as an
alternative fuel.
Although many trade groups, academics and governmental agencies
have supported ethanol as a fuel additive that promotes a
cleaner environment, others have criticized ethanol production
as consuming considerably more energy and emitting more
greenhouse gases than other biofuels and as potentially
depleting water resources. Other studies have suggested that
corn-based ethanol is less efficient than ethanol produced from
switchgrass or wheat grain and that it negatively impacts
consumers by causing prices for dairy, meat and other foodstuffs
from livestock that consume corn to increase. If these views
gain acceptance, support for existing measures promoting use and
domestic production of corn-based ethanol could decline, leading
to reduction or repeal of these measures. These views could also
negatively impact public perception of the ethanol industry and
acceptance of ethanol as an alternative fuel.
We face
intense competition from competing ethanol and other fuel
additive producers.
Competition in the ethanol industry is intense. We face
formidable competition in every aspect of our business from
established producers of ethanol, including Archer Daniels
Midland Company and Cargill, Inc., and from other companies that
are seeking to develop large-scale ethanol plants and alliances.
According to the RFA, the top ten producers accounted for
approximately 56% of the ethanol production capacity in the
U.S., and we accounted for approximately 4.9% of the ethanol
production capacity in the U.S. Some of our
44
competitors are divisions of substantially larger enterprises
and have substantially greater financial resources than we do.
Smaller competitors also pose a threat. Farmer-owned
cooperatives and independent firms consisting of groups of
individual farmers and investors have been able to compete
successfully in the ethanol industry. These smaller competitors
operate smaller plants which may not affect the local price of
corn grown in proximity to the plant as much as larger plants
like ours affect these prices. In addition, many of these
smaller competitors are farmer-owned and often require their
farmer-owners to commit to selling them a certain amount of corn
as a requirement of ownership. A significant portion of
production capacity in our industry consists of smaller-sized
plants.
We expect competition to increase as the ethanol industry
becomes more widely known and demand for ethanol increases. Most
new ethanol plants in development across the country are
independently owned. In addition, various investors could
heavily invest in ethanol plants and oversupply ethanol,
resulting in higher raw material costs and lower ethanol price
levels that could materially adversely affect our business,
results of operations and financial condition.
We also face increasing competition from international
suppliers. Although there is a tariff on foreign-produced
ethanol (which is scheduled to expire in 2009) that is
roughly equivalent to the federal ethanol tax incentive, ethanol
imports equivalent to up to 7.0% of total domestic production
from certain countries were exempted from this tariff under the
Caribbean Basin Initiative to spur economic development in
Central America and the Caribbean. Currently, international
suppliers produce ethanol primarily from sugar cane, which is a
significantly more efficient raw material from which to produce
ethanol than corn, and have cost structures that are
substantially lower than ours.
Any increase in domestic or foreign competition could cause us
to reduce our prices and take other steps to attempt to compete
more effectively, which could materially adversely affect our
business, results of operations and financial condition.
We have a
limited operating history and a history of losses, and our
business may not be as successful as it envisions.
We were incorporated in October 2004 and did not engage in any
revenue producing activities until we acquired United Bio
Energy, LLC, or UBE, on May 1, 2005. On April 30,
2006, we acquired our first operating ethanol plant and in May
2006, began recording revenues from our ethanol production
activity. Accordingly, we have a limited operating history from
which one can evaluate our business and prospects. Our prospects
must be considered in light of the risks and uncertainties
encountered by an early-stage company and in rapidly evolving
conditions, such as the ethanol market, where supply and demand
may change significantly in a short period of time.
Some of these risks relate to our potential inability to:
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effectively manage our business and operations;
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recruit and retain key personnel;
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successfully maintain our low-cost structure as we expand the
scale of our business;
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manage rapid growth in personnel and operations;
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develop new products that complement our existing
business; and
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successfully address the other risks described throughout this
report on
Form 10-Q.
|
If we cannot successfully address these risks, our business,
future results of operations and financial condition may be
materially adversely affected, and we may experience operating
losses in the future.
45
Potential
future acquisitions could be difficult to find and integrate,
divert the attention of key personnel, disrupt our business,
dilute shareholder value and adversely affect our financial
results.
As part of our business strategy, we may consider acquisitions
of other businesses, building sites, plants, storage or
distribution facilities and selected infrastructure. There is no
assurance, however, that we will determine to pursue any of
these opportunities or that if we determine to pursue them that
we will be successful.
Acquisitions involve numerous risks, any of which could harm our
business, including:
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difficulties in integrating the operations, technologies,
products, existing contracts, accounting processes and workforce
of the target and realizing the anticipated synergies of the
combined businesses;
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difficulties in supporting and transitioning customers, if any,
of the target company or assets;
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diversion of financial and management resources from existing
operations;
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the price we pay or other resources that we devote may exceed
the value we realize, or the value we could have realized if we
had allocated the purchase price or other resources to another
opportunity;
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risks of entering new markets or areas in which we have limited
or no experience or are outside our core competencies;
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potential loss of key employees, customers and strategic
alliances from either our current business or the business of
the target;
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assumption of unanticipated problems or latent liabilities, such
as problems with the quality of the products of the
target; and
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inability to generate sufficient revenue to offset acquisition
costs.
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We also may pursue acquisitions through joint ventures or
partnerships. Partnerships and joint ventures typically involve
restrictions on actions that the partnership or joint venture
may take without the approval of the partners. These types of
provisions may limit our ability to manage a partnership or
joint venture in a manner that is in our best interest but is
opposed by our other partner or partners.
Future acquisitions may involve the issuance of our equity
securities as payment or in connection with financing the
business or assets acquired, and as a result, could dilute the
ownership interests of current shareholders. In addition, we may
need to incur additional debt and related interest expense in
order to consummate these transactions, as well as to assume
unforeseen liabilities, all of which could have a material
adverse effect on our business, results of operations and
financial condition. The failure to successfully evaluate and
execute acquisitions or otherwise adequately address the risks
associated with acquisitions could have a material adverse
effect on our business, results of operations and financial
condition.
We may
not be able to implement our expansion strategy as planned or at
all.
We have four operational ethanol plants and four ethanol plants
under construction, which are in various stages of construction,
with commencement of operations scheduled in 2008. We also
continue to evaluate potential future opportunities for growth
and development.
Development, construction and expansion of ethanol plants are
subject to a number of risks, any of which could prevent us from
commencing operations at a particular plant as expected or at
all, including cost overruns, zoning and permitting matters,
adverse weather, defects in materials and workmanship, labor and
material shortages, transportation constraints, construction
change orders, site changes, workforce issues, the availability
of sufficient quantities of water of suitable quality and other
unforeseen difficulties. For example, a lawsuit is currently
pending against our joint venture partner in the Grinnell
project, and certain other defendants, including the county
zoning board, challenging a decision to rezone the land intended
for the Grinnell plant to permit construction of an ethanol
plant. A majority of the contested issues were favorably decided
for our joint venture partner on summary judgment, with our
joint venture partner prevailing on the remaining issues at
trial in September 2007. However, the plaintiff has requested a
reconsideration of the
46
decision, and in that the plaintiff was unsuccessful, we believe
that an appeal is likely. Construction in the upper Midwest,
where many of our plants are located, can also be particularly
difficult in the winter because of delays related to adverse
weather. In addition, during the expansion of an existing plant,
we may be forced to suspend or curtail our operations at such
plant, which would decrease our ethanol production and reduce
its revenues.
As of September 30, 2007, total costs to complete our
plants under construction are expected to be approximately
$265.1 million, of which we anticipate funding
approximately $14.8 million with cash on hand and cash
generated from operations. At this time Grinnell has not entered
into a credit facility to construct its ethanol plant, and we
have put on hold any further funding of the Grinnell plant until
the pending lawsuits are satisfactorily resolved and a credit
facility is obtained. To the extent that our cash on hand and
cash generated from operations are not sufficient, additional
financing will be required to fully fund future construction
projects. We may not have access to required financing on
acceptable terms or at all.
We intend to finance the expansion of our business in part with
additional indebtedness and may also do so by issuing additional
equity securities. We could face financial risks associated with
incurring additional indebtedness, such as reducing our
liquidity and access to financial markets and increasing the
amount of cash flow required to service such indebtedness, or
associated with issuing additional equity, such as dilution of
ownership and earnings. We face additional risks associated with
financing our expansion strategy due to the significant
limitations imposed on our ability to incur or service
additional debt or grant security interests on our assets
contained in our existing debt financing agreements.
The significant expansion of ethanol production capacity
currently underway in the U.S. may also impede our
expansion strategy. As a result of this expansion, we believe
that there is increasing competition for suitable sites for
ethanol plants, and we may not find suitable sites for
construction of new plants or other suitable expansion
opportunities. Even if we are able to identify suitable sites or
opportunities, we may not be able to secure the services and
products from the contractors, engineering firms, construction
firms and equipment suppliers necessary to build our ethanol
plants on a timely basis or on acceptable economic terms.
Our expansion strategy is particularly dependent on the
continued availability of construction and engineering services
provided to us by Fagen, Inc., an entity controlled by one of
our principal shareholders, Ron Fagen. We believe that Fagen has
constructed over 65% of the ethanol production capacity built in
the U.S. over the past six years. Although we have entered
into design-build agreements with Fagen, Inc. for each of our
plants under construction, including our Grinnell project, and
master design-build agreements with Fagen that provide
additional build slots through 2010, if Fagen fails to perform
under those agreements, our ability to meet our expansion goals
would be limited. Fagen has also entered into design-build
contracts with other parties seeking to build ethanol plants and
has invested and may continue to invest in other ethanol
producers. As a result, Fagen, Inc. may have a conflict of
interest in performing its obligations under its design-build
agreements with us which could delay or prevent our expansion
strategy.
We must also obtain numerous regulatory approvals and permits in
order to construct and operate additional or expanded plants.
These requirements may not be satisfied in a timely manner or at
all. Our exposure to permitting risks may be exacerbated because
we may begin construction on certain of our plants and incur
substantial costs without first obtaining all permits necessary
to operate an ethanol plant at that site. In the event that we
fail to ultimately obtain all necessary permits, we would be
forced to abandon the project and lose the benefit of any
construction costs already incurred. In addition, federal and
state governmental requirements may substantially increase our
costs, which could have a material adverse effect on our
business, results of operations and financial condition.
Our expansion plans may also result in other unanticipated
adverse consequences, such as the diversion of managements
attention from our existing plants and other businesses.
Accordingly, we may not be able to implement our expansion
strategy as planned, or at all. We may not find additional
appropriate sites for new ethanol plants, and we may not be able
to finance, construct, develop or operate these new or expanded
plants successfully.
47
We engage
in hedging transactions which involve risks that can harm our
business.
In an attempt to offset some of the effects of volatility of
ethanol prices and costs of commodities, we may enter into cash
fixed-price contracts to sell a portion of our ethanol and
distillers grains production or purchase a portion of our corn
or natural gas requirements. We may use exchange-traded futures
contracts and options to manage commodity risk. The impact of
these activities depends upon, among other things, the prices
involved and our ability to sell sufficient products to use all
of the corn and natural gas for which we have futures contracts.
Hedging arrangements also expose us to the risk of financial
loss in situations where the other party to the hedging contract
defaults on its contract or, in the case of exchange-traded
contracts, where there is a change in the expected differential
between the underlying price in the hedging agreement and the
actual prices paid or received by us. Hedging activities can
themselves result in losses when a position is purchased in a
declining market or a position is sold in a rising market. A
hedge position is often settled in the same time frame as the
physical commodity is either purchased (corn and natural gas) or
sold (ethanol). We may experience hedging losses in the future.
We also vary the amount of hedging or other price mitigation
strategies we undertake, and we may choose not to engage in
hedging transactions at all and, as a result, our business,
results of operations and financial condition may be materially
adversely affected by increases in the price of corn or natural
gas or decreases in the price of ethanol.
Operational
difficulties at our plants could negatively impact our sales
volumes and could cause us to incur substantial
losses.
Our operations are subject to labor disruptions, unscheduled
downtime and other operational hazards inherent in our industry,
such as equipment failures, fires, explosions, abnormal
pressures, blowouts, pipeline ruptures, transportation accidents
and natural disasters. Some of these operational hazards may
cause personal injury or loss of life, severe damage to or
destruction of property and equipment or environmental damage,
and may result in suspension of operations and the imposition of
civil or criminal penalties. Our insurance may not be adequate
to fully cover the potential operational hazards described above
or we may not be able to renew this insurance on commercially
reasonable terms or at all.
Moreover, our plants may not operate as planned or expected. All
of our plants have or will have a specified nameplate capacity
which represents the production capacity specified in the
applicable design-build agreement. The builder generally tests
the capacity of the plant during the start of its operations.
But based on our experience in operating similar plants, we
generally expect our plants to produce in excess of their
nameplate capacity. The operation of our plants is and will be,
however, subject to various uncertainties relating to our
ability to implement the necessary process improvements required
to achieve these increased production capacities. As a result,
our plants may not produce ethanol and distillers grains at the
levels we expect. In the event any of our plants do not run at
their nameplate or our increased expected capacity levels, our
business, results of operations and financial condition may be
materially adversely affected.
We may be
adversely affected by environmental, health and safety laws,
regulations and liabilities.
We are or will become subject to various federal, state and
local environmental laws and regulations, including those
relating to the discharge of materials into the air, water and
ground, the generation, storage, handling, use, transportation
and disposal of hazardous materials, and the health and safety
of our employees. In particular, each ethanol plant we intend to
operate will be subject to environmental regulation by the state
in which the plant is located and by the EPA. These laws,
regulations and permits can often require expensive pollution
control equipment or operational changes to limit actual or
potential impacts on the environment. A violation of these laws
and regulations or permit conditions can result in substantial
fines, damage to natural resources, criminal sanctions, permit
revocations
and/or
plant
shutdowns.
In addition, to construct and operate our ethanol plants, we
will need to obtain and comply with a number of permit
requirements. As a condition to granting necessary permits,
regulators could make demands that increase our costs of
construction and operations, in which case we could be forced to
obtain additional debt or equity capital. For example, we are
currently facing increased construction costs for our
Janesville, Minnesota plant in order to meet unanticipated water
discharge requirements and we expect to incur additional
48
construction costs of approximately $5.0 to $6.0 million in
order to meet these requirements. Permit conditions could also
restrict or limit the extent of our operations. We cannot assure
you that we will be able to obtain and comply with all necessary
permits to construct or operate our ethanol plants. Failure to
obtain and comply with all applicable permits and licenses could
halt our construction and could subject us to future claims.
Environmental issues, such as contamination and compliance with
applicable environmental standards, could arise at any time
during the construction and operation of our ethanol plants. If
this occurs, it would require us to spend significant resources
to remedy the issues and may delay or prevent construction or
operation of our ethanol plants. This would significantly
increase the cost of these projects.
We may be liable for the investigation and cleanup of
environmental contamination at each of the properties that we
own or operate and at off-site locations where we arrange for
the disposal of hazardous substances. If these substances have
been or are disposed of or released at sites that undergo
investigation
and/or
remediation by regulatory agencies, we may be responsible under
the CERCLA or other environmental laws for all or part of the
costs of investigation
and/or
remediation, and for damages to natural resources. We may also
be subject to related claims by private parties, including our
employees and property owners or residents near our plants,
alleging property damage and personal injury due to exposure to
hazardous or other materials at or from those plants.
Additionally, employees, property owners or residents near our
ethanol plants could object to the air emissions or water
discharges from our ethanol plants. Ethanol production has been
known to produce an unpleasant odor. Environmental and public
nuisance claims or toxic tort claims could be brought against us
as a result of this odor or other releases to the air or water.
Some of these matters may require us to expend significant
resources for investigation, cleanup, installation of control
technologies or other compliance-related items, or other costs.
In addition, new laws, new interpretations of existing laws,
increased governmental enforcement of environmental laws or
other developments could require us to make additional
significant expenditures. Continued government and public
emphasis on environmental issues can be expected to result in
increased future investments for environmental controls at our
plants. For example, federal and state environmental authorities
have recently been investigating alleged excess volatile organic
compounds and other air emissions from certain U.S. ethanol
plants. Present and future environmental laws and regulations
(and interpretations thereof) applicable to our operations, more
vigorous enforcement policies and discovery of currently unknown
conditions may require substantial expenditures that could have
a material adverse effect on our business, results of operations
and financial condition.
The hazards and risks associated with producing and transporting
our products (such as fires, natural disasters, explosions, and
abnormal pressures and blowouts) may also result in personal
injury claims by third-parties or damage to property owned by us
or by third-parties. As protection against operating hazards, we
intend to maintain insurance coverage against some, but not all,
potential losses. However, we could sustain losses for
uninsurable or uninsured events, or in amounts in excess of
existing insurance coverage. Events that result in significant
personal injury to third-parties or damage to property owned by
us or third-parties or other losses that are not fully covered
by insurance could have a material adverse effect on our
business, results of operations and financial condition.
We do not
own or control some of the assets we depend on to operate our
business.
We are generally contractually obligated to sell 100% of the
ethanol we produce to Provista, an entity in which we only own a
50% equity interest. The other 50% of Provista is owned by CHS,
Inc. Provista is governed by an amended and restated operating
agreement, which provides for the designation of a manager to
manage its business and affairs. Pursuant to the amended and
restated operating agreement and the related management
agreement, we, along with CHS, designated CHS as the manager of
Provista. The management agreement provides CHS with broad
authority to manage the business of Provista, subject to certain
actions that CHS may not take without our approval. Because we
do not manage Provista, our ability to control the marketing of
our ethanol is limited, and we may be prevented from taking
actions with respect to the marketing of our ethanol that we
believe to be in our own best interests.
49
In addition, Provista leases approximately 1,200 railcars and
employs the personnel upon whom we rely to sell our ethanol. Our
marketing agreement with Provista has a current term through
November 30, 2008, and thereafter will automatically renew
for one-year additional terms, unless either party provides the
other with ninety days written notice of non-renewal. Moreover,
pursuant to the amended and restated operating agreement,
beginning on April 1, 2009, either member of Provista may
initiate a buy-sell mechanism. Under this mechanism, after
receiving notice of the initiation of the buy-sell mechanism,
the non-initiating member must elect to either sell all of its
interests in Provista to the initiating member or purchase all
of the initiating members interest in Provista, in each
case, at a purchase price not less than a specified multiple of
Provistas EBITDA. If our marketing agreement with Provista
is terminated, or if we lose all of our interests in Provista
pursuant to the buy-sell mechanism, we may be unable to obtain
replacement third-party marketing services on similar terms or
at all or to acquire the railcars and develop the necessary
internal resources to market our ethanol directly. As a result,
any such termination or loss of all of our interests in Provista
could have a material adverse effect on our business, results of
operations and financial condition.
In addition, in connection with the development of future
ethanol plants, we may enter into joint venture arrangements
with third-party entities to own and operate such plants. For
example, we formed a joint venture with Big River Resources, LLC
to construct an ethanol plant near Grinnell, Iowa. Under the
terms of this arrangement, each of us and Big River Resources,
LLC will own 50% of the entity that will own the plant. If we
own less than 100% of the entities that operate certain of its
ethanol plants, we may be limited in our ability to operate the
plant in a manner that maximizes benefits for us.
Disruptions
to infrastructure, or in the supply of fuel, natural gas or
water, could materially and adversely affect our
business.
Our business depends on the continuing availability of rail,
road, port, storage and distribution infrastructure. Any
disruptions in this infrastructure network, whether caused by
labor difficulties, earthquakes, storms, other natural
disasters, human error or malfeasance or other reasons, could
have a material adverse effect on our business. We rely upon
third-parties to maintain the rail lines from our plants to the
national rail network, and any failure on their part to maintain
the lines could impede our delivery of products, impose
additional costs on us and could have a material adverse effect
on our business, results of operations and financial condition.
Our business also depends on the continuing availability of raw
materials, including fuel and natural gas. The production of
ethanol, from the planting of corn to the distribution of
ethanol to refiners, is highly energy-intensive. Significant
amounts of fuel and natural gas are required for the growing,
fertilizing and harvesting of corn, as well as for the
fermentation, distillation and transportation of ethanol and the
drying of distillers grains. A serious disruption in supplies of
fuel or natural gas, including as a result of delivery
curtailments to industrial customers due to extremely cold
weather, or significant increases in the prices of fuel or
natural gas, could significantly reduce the availability of raw
materials at our plants, increase our production costs and could
have a material adverse effect on our business, results of
operations and financial condition.
Our ethanol plants also require a significant and uninterrupted
supply of water of suitable quality to operate. If there is an
interruption in the supply of water for any reason, we may be
required to halt production at one or more of our plants. If
production is halted at one or more of our plants for an
extended period of time, it could have a material adverse effect
on our business, results of operations and financial condition.
Our
historical financial information is not comparable to our
current financial condition and results of operations.
We did not engage in any revenue producing activities from our
inception on October 28, 2004 until we acquired UBE on
May 1, 2005. As a result, our results of operations for
periods subsequent to our acquisition of UBE are not comparable
to our results of operations for prior periods.
We also did not produce any ethanol during 2004 or 2005, and all
of our revenue producing operating results during 2005 were
attributable to the conduct of our services business after the
consummation of the UBE acquisition on May 1, 2005.
50
We acquired our first operating ethanol plant, Platte Valley, on
April 30, 2006, and effective May 1, 2006, it began
recognizing revenue from the production of ethanol. As a result,
our results of operations for periods subsequent to our
acquisition of Platte Valley are not comparable to our results
of operations for prior periods. Moreover, in September 2006,
our Woodbury plant began operations. In November 2006, we
completed the expansion of our Platte Valley plant, in December
2006, we began production at our Albert City plant and in May
2007, we began production at our Ord plant. We currently have
four other plants under construction following our recent
acquisition of Millennium Ethanol, LLCs Marion, South
Dakota plant under construction. To the extent we acquire or
develop additional production capacity, the comparability of our
results of operations will be further limited.
Accordingly, our historical financial information and financial
information for periods in which we experience a significant
expansion of our ethanol production capacity may be of limited
use in evaluating our financial performance and comparing it to
other periods.
Our
managements time and attention will be divided among our
ethanol plants, and our ethanol plants will be part of one
common management strategy.
Our business model calls for us to form wholly-owned business
entities to own each of our ethanol plants, which will be
managed by a centralized management team. The demands on our
managements time from one ethanol plant may, from time to
time, compete with the time and attention required for the
operation of other ethanol plants. This division of our
managements time and attention among our ethanol plants
may make it difficult for us to realize the maximum return from
any one plant. Further, to reduce expenses and create
efficiencies, we intend to manage each of our ethanol plants in
a similar manner. This common management strategy may also
result in difficulties in achieving the maximum return from any
one plant. If our common management strategy is not successful
or if we are not able to address the unique challenges of each
ethanol plant, the impact of this arrangement likely will be
spread among all of our ethanol plants, resulting in greater
potential harm to our business than if each ethanol plant were
operated independently.
Competition
for qualified personnel in the ethanol industry is intense and
we may not be able to hire and retain qualified personnel to
operate our ethanol plants.
Our success depends in part on our ability to attract and retain
competent personnel. For each of our plants, we must hire
qualified managers, engineers, operations and other personnel,
which can be challenging in a rural community. Competition for
both managers and plant employees in the ethanol industry is
intense, and we may not be able to attract and retain qualified
personnel. If we are unable to hire and retain productive and
competent personnel, our expansion strategy may be adversely
affected, the amount of ethanol we produce may decrease and we
may not be able to efficiently operate our ethanol plants and
execute our business strategy.
Technological
advances could significantly decrease the cost of producing
ethanol or result in the production of higher-quality ethanol,
and if we are unable to adopt or incorporate technological
advances into our operations, our proposed ethanol plants could
become uncompetitive or obsolete.
We expect that technological advances in the processes and
procedures for processing ethanol will continue to occur. It is
possible that those advances could make the processes and
procedures that we utilize at our ethanol plants less efficient
or obsolete. These advances could also allow our competitors to
produce ethanol at a lower cost than us. If we are unable to
adopt or incorporate technological advances, our ethanol
production methods and processes could be less efficient than
those of our competitors, which could cause our ethanol plants
to become uncompetitive.
Ethanol production methods are also constantly advancing. The
current trend in ethanol production research is to develop an
efficient method of producing ethanol from cellulose-based
biomass such as agricultural waste, forest residue and municipal
solid waste. This trend is driven by the fact that
cellulose-based biomass is generally cheaper than corn and
producing ethanol from cellulose-based biomass would create
opportunities to produce ethanol in areas that are unable to
grow corn. Another trend in ethanol
51
production research is to produce ethanol through a chemical or
thermal process, rather than a fermentation process, thereby
significantly increasing the ethanol yield per pound of
feedstock. Although current technology does not allow these
production methods to be competitive, new technologies may
develop that would allow these methods to become viable means of
ethanol production in the future. If we are unable to adopt or
incorporate these advances into our operations, our cost of
producing ethanol could be significantly higher than those of
our competitors, which could make our ethanol plants obsolete.
Modifying our plants to use the new inputs and technologies will
likely require material investment.
In addition, alternative fuels, additives and oxygenates are
continually under development. Alternative fuel additives that
can replace ethanol may be developed, which may decrease the
demand for ethanol. It is also possible that technological
advances in engine and exhaust system design and performance
could reduce the use of oxygenates, which would lower the demand
for ethanol, and our business, results of operations and
financial condition may be materially adversely affected.
We have a
significant amount of debt, and our existing debt financing
agreements contain, and our future debt financing agreements may
contain, restrictive covenants that limit distributions and
impose restrictions on the operation of our business. Our debt
level or our failure, or the failure of any of our subsidiaries,
to comply with applicable debt financing covenants and
agreements could have a material adverse effect on our business,
results of operations and financial condition.
As of September 30, 2007, our total debt was
$347.1 million. As of September 30, 2007, we had total
available borrowing capacity of $312.5 million. We plan to incur
significant additional debt to complete our four ethanol plants
currently under construction. We also may incur additional debt
to fund operations at our plants or in connection with other
development projects or acquisitions.
The use of debt financing makes it more difficult for us to
operate because we must make principal and interest payments on
the indebtedness and abide by covenants contained in our debt
financing agreements, including the indenture governing the
notes. The level of our debt may have important implications on
our operations, including, among other things:
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limiting our ability to obtain additional debt or equity
financing;
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making us vulnerable to increases in prevailing interest rates;
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placing us at a competitive disadvantage because we may be
substantially more leveraged than some of our competitors;
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subjecting all or substantially all of our assets to liens,
which means that there may be no assets left for shareholders in
the event of a liquidation;
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limiting our ability to adjust to changing market conditions,
which could make us more vulnerable to a downturn in the general
economic conditions of our business; and
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limiting our ability to make business and operational decisions
regarding our business and our subsidiaries, including, among
other things, limiting our ability to pay dividends to our
shareholders, make capital improvements, sell or purchase assets
or engage in transactions we deem to be appropriate and in our
best interest.
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The terms of our existing debt financing agreements contain, and
any future debt financing agreement we enter into may contain,
financial, maintenance, organizational, operational and other
restrictive covenants. If we are unable to comply with these
covenants or service our debt, we may lose control of our
business and be forced to reduce or delay planned capital
expenditures, sell assets, restructure our indebtedness or
submit to foreclosure proceedings, all of which could result in
a material adverse effect upon our business, results of
operations and financial condition. Our debt arrangements may
also include subordinated debt, which may contain even more
restrictions and be on less favorable terms than our senior
debt. If we issue subordinated debt, we may have to give the
lender warrants, put rights, conversion rights, the right to
take control of our business in the event of a default or other
rights and benefits as the lender may require.
52
Our
management and auditors have identified material weaknesses in
the design and operation of our internal controls that, if not
properly remediated, could result in material misstatements in
our financial statements in future periods.
With respect to the audit of our 2006 financial statements, an
independent registered public accounting firm issued a letter to
our audit committee in which they identified a material weakness
related to the financial close process. A material
weakness is a significant deficiency, or a combination of
significant deficiencies, that results in more than a remote
likelihood that a material misstatement of the financial
statements will not be prevented or detected. A
significant deficiency is a control deficiency, or a
combination of control deficiencies, that adversely affects an
entitys ability to initiate, authorize, record, process or
report financial data reliably in accordance with generally
accepted accounting principles such that there is more than a
remote likelihood that a misstatement of the entitys
financial statements that is more than inconsequential will not
be prevented or detected.
There were adjustments to our financial statements and other
factors during the course of our 2006 audit which impacted our
closing process and delayed the preparation of our consolidated
financial statements, including all required disclosures, in a
timely manner. The audit adjustments to our original trial
balance impacted net income and a number of balance sheet
accounts. The most significant of these entries were to adjust
capitalized interest and deferred income taxes. In addition,
several of these adjustments were not identified until over two
months after our year end. These deficiencies constituted a
material weakness in our financial close process.
The auditors recommended that we continue to create and refine a
structure in which critical accounting policies and estimates
are identified, and together with other complex areas, are
subject to multiple reviews by accounting personnel. The
auditors further recommended that we enhance and test our
year-end financial close process during the quarterly
Form 10-Q
preparation process in 2007.
With respect to our 2005 audit, the auditors identified a
material weakness relating to our accounting for certain of our
business transactions. During 2005, we entered into numerous
transactions which had complex accounting ramifications,
including business combination, stock based compensation, lease,
plant construction and debt restructuring transactions. Due to
our inability to identify or properly record these transactions
in a timely manner, numerous audit adjustments were required.
The auditors recommended that we provide additional resources to
accounting personnel and that we implement additional control
procedures.
With respect to our 2004 audit, the auditors identified a
reportable condition relating to the inadequate segregation of
accounting and financial duties within US Bio Resource Group,
the company that provided us with management and administrative
services, including accounting services. On November 17,
2005, we terminated the administrative services agreement with
US Bio Resource Group.
In connection with Platte Valleys 2004 audit, the auditors
identified internal control deficiencies relating to the
separation of accounting functions, the duties of Platte
Valleys controllers and Platte Valleys accounting
procedures manual. We acquired Platte Valley on April 30,
2006.
In response to these matters, we have implemented an internal
audit function, and our board of directors established an audit
committee. In addition, we are in the process of upgrading our
systems, implementing additional financial and management
controls, and reporting systems and procedures. During 2006, we
hired a new Chief Financial Officer, a tax director, an
information systems officer and additional accounting, internal
audit and finance staff. We are also currently undergoing a
comprehensive effort in preparation for compliance with
Section 404 of the Sarbanes-Oxley Act of 2002. This effort,
under the direction of senior management, includes documentation
and testing of our general computer controls and business
processes. We are currently in the process of formalizing an
internal audit plan that includes performing a risk assessment,
establishing a reporting methodology and testing internal
controls and procedures over financial reporting.
If the remedial policies and procedures we are implementing are
insufficient to address the identified material weakness, or if
additional significant deficiencies or material weaknesses in
our internal controls are discovered in the future, we may fail
to meet our future reporting obligations, our financial
statements may contain material misstatements and our operating
results may be adversely affected. Any such failure could
53
also adversely affect the results of the periodic management
evaluations and annual auditor attestation reports regarding the
effectiveness of our internal control over financial
reporting, which will be required once the SECs
rules under Section 404 of the Sarbanes-Oxley Act of 2002
become applicable to us.
As a
result of our IPO in December 2006, we are subject to financial
reporting and other requirements for which our accounting,
internal audit and other management systems and resources may
not be adequately prepared.
As a result of our IPO, we are subject to reporting and other
obligations under the Securities Exchange Act of 1934, as
amended, or the Exchange Act. These reporting and other
obligations place significant demands on our management,
administrative, operational, internal audit and accounting
resources. If we are unable to meet these demands in a timely
and effective fashion, our ability to comply with our financial
reporting requirements and other rules that apply to us could be
impaired. Any failure to maintain effective internal controls
could have a material adverse effect on our business, results of
operations and financial condition.
As we
expand our ethanol production business, we may become limited in
our ability to provide services to third-party ethanol
producers.
We provide ethanol and distillers grains marketing, grain
procurement, risk consulting and facilities management services
to third-party ethanol producers. In the past, our services
business was our sole source of revenue. As we expand our
ethanol production business, third-party ethanol producers may
desire to terminate their existing service arrangements with us
due to competitive concerns. Similarly, it has become more
difficult for us to attract new customers to our services
business. Due to the uncertain prospects of our services
business, we recorded a $2.5 million impairment charge in
September 2007. If existing customers terminate their
arrangements with us, or if potential customers continue to
refuse to engage our services, our business, results of
operations and financial condition may be materially adversely
affected.
We are a
holding company, and there are limitations on our ability to
receive distributions from our subsidiaries.
We conduct all of our operations through subsidiaries and are
dependent upon dividends or other intercompany transfers of
funds from our subsidiaries to meet our obligations. Moreover,
substantially all of our subsidiaries are currently, or are
expected in the future to be, limited in their ability to pay
dividends or make distributions to us by the terms of their
financing agreements.
Certain
of our shareholders exert significant influence over us. Their
interests may not coincide with ours or the interests of our
shareholders, and they may make decisions with which we or our
shareholders may disagree.
Gordon Ommen, our chief executive officer, Ron Fagen and CHS
Inc. beneficially own approximately 8%, 19% and 20% of our
common stock, respectively, and our executive officers,
directors and principal shareholders, i.e., shareholders holding
more than 5% of our common stock, including Gordon Ommen, Ron
Fagen and CHS Inc., together control approximately 50% of our
common stock. As a result, these shareholders, acting
individually or together, could significantly influence our
management and affairs and all matters requiring shareholder
approval, including the election of directors and approval of
significant corporate transactions. This concentration of
ownership may also have the effect of delaying or preventing a
change in control of our company and might affect the market
price of our common stock.
The interests of these shareholders may not coincide with our
interests or the interests of our shareholders. For instance,
Capitaline Advisors, LLC, a private equity investment management
firm specializing in renewable energy investments which is 100%
owned and controlled by Gordon Ommen, and Fagen, Inc., the
leading builder of ethanol plants in the U.S. which is
owned and controlled by Ron Fagen, have invested and may
continue to invest in a number of other ethanol producers. For
example, Capitaline Advisors currently has an investment in Big
River Resources, LLC, our joint venture partner for the Grinnell
plant. As a result of
54
these and other potential conflicting interests, these existing
shareholders may make decisions with respect to us with which we
or our shareholders may disagree.
|
|
Item 2:
|
UNREGISTERED
SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
|
|
|
(b)
|
Use of
Proceeds from IPO
|
In connection with our IPO on December 15, 2006, our
Registration Statements on
Form S-1
(Registration Nos.
333-136279
and
333-139364)
became effective. Pursuant to these Registration Statements, in
December 2006 we sold an aggregate of 11,500,000 shares of
common stock, including 1,500,000 shares sold pursuant to
an option granted to the underwriters to cover over-allotments.
As of September 30, 2007, we had applied the
$149.7 million of net proceeds we received from the
offering as follows (dollars in millions):
|
|
|
|
|
Repayment of subordinated credit facilities
|
|
$
|
6.8
|
|
Construction of facilities
|
|
|
142.9
|
(1)
|
Temporary investments
|
|
|
|
|
|
|
|
(1)
|
|
Proceeds were used to fund construction costs at our Hankinson,
Janesville and Dyersville plants. Of this amount,
$112.4 million was paid to Fagen Inc., an entity controlled
by Roland Fagen, one of our largest shareholders.
|
|
|
|
|
|
Exhibit No.
|
|
Description
|
|
|
10
|
.1
|
|
Lease Agreement, dated July 10, 2007, between CHS, Inc. and
US BioEnergy Corporation (incorporated by reference to
Exhibit 10.1 to US BioEnergys
Form 8-K,
filed with the SEC on July 10, 2007, File
No. 001-33203)
|
|
10
|
.2
|
|
Amendment No. 1 to Fourth Supplement to the Master Loan
Agreement (Term Revolving Loan) dated October 19, 2007 by and
between US Bio Woodbury, LLC and AgStar Financial Services, PCA.
|
|
10
|
.3
|
|
Amendment No. 1 To the Credit Agreement dated October 19, 2007
by and between US Bio Ord, LLC and AgStar Financial Services,
PCA.
|
|
10
|
.4
|
|
Amendment No. 1 To the Credit Agreement dated October 19, 2007
by and between US Bio Hankinson, LLC and AgStar Financial
Services, PCA.
|
|
10
|
.5
|
|
Amendment No. 1 To the Credit Agreement dated October 19, 2007
by and between US Bio Janesville, LLC and AgStar Financial
Services, PCA.
|
|
10
|
.6
|
|
Amendment No. 1 To the Credit Agreement dated October 19, 2007
by and between US Bio Dyersville, LLC and AgStar Financial
Services, PCA.
|
|
10
|
.7
|
|
Amendment No. 1 To the Credit Agreement dated October 19, 2007
by and between US Bio Platte Valley, LLC and AgStar Financial
Services, PCA.
|
|
10
|
.8
|
|
Amendment No. 2 To the Credit Agreement dated November 1, 2007
by and between US Bio Dyersville, LLC and AgStar Financial
Services, PCA.
|
|
10
|
.9
|
|
Amendment No. 2 To the Amended and Restated Master Loan
Agreement dated November 1, 2007 by and between US Bio Albert
City, LLC and AgStar Financial Services, PCA.
|
|
10
|
.10
|
|
Amendment No. 1 To the Amended and Restated Master Loan
Agreement dated as of October 19, 2007 by and between US Bio
Albert City, LLC and AgStar Financial Services, PCA.
|
|
10
|
.11
|
|
Amendment No. 1 to Second Supplement to the Master Loan
Agreement (Revolving Loan) dated as of October 19, 2007 by and
between US Bio Albert City, LLC and AgStar Financial Services,
PCA.
|
|
10
|
.12
|
|
Amendment No. 1 to Third Supplement to the Master Loan Agreement
(Term Loan) dated as of October 19, 2007 by and between US Bio
Albert City, LLC and AgStar Financial Services, PCA.
|
|
10
|
.13
|
|
Allonge (Term Note) dated as of October 19, 2007 to the Term
Note dated February 26, 2007, executed by US Bio Albert City,
LLC.
|
55
|
|
|
|
|
Exhibit No.
|
|
Description
|
|
|
10
|
.14
|
|
Amendment No. 1 to Fourth Supplement to the Master Loan
Agreement (Term Revolving Loan) dated as of October 19, 2007 by
and between US Bio Albert City, LLC and AgStar Financial
Services, PCA.
|
|
10
|
.15
|
|
Allonge dated as of October 19, 2007 to the Term Revolving Note
dated February 26, 2007 executed by US Bio Albert City, LLC.
|
|
10
|
.16
|
|
Amendment No. 2 to Amended and Restated Second Supplement
to the Master Loan Agreement (Revolving Loan) dated
November 1, 2007, by and between US Bio Woodbury, LLC and
AgStar Financial Services, PCA.
|
|
10
|
.17
|
|
Allonge to Amended and Restated Revolving Note dated
November 1, 2007, executed by US Bio Woodbury, LLC.
|
|
10
|
.18
|
|
Amendment No. 2 to Master Loan Agreement dated October 19, 2007,
by and between US Bio Woodbury, LLC and AgStar Financial
Services, PCA.
|
|
10
|
.19
|
|
Amendment No. 1 to Amended and Restated Second Supplement to the
Master Loan Agreement (Revolving Loan) dated October 19, 2007 by
and between US Bio Woodbury, LLC and AgStar Financial Services,
PCA.
|
|
10
|
.20
|
|
Amendment No. 1 to Third Supplement to the Master Loan Agreement
(Term Loan) dated October 19, 2007 by and between US Bio
Woodbury, LLC and AgStar Financial Services, PCA.
|
|
10
|
.21
|
|
Allonge (Term Note) dated October 19, 2007 to the Term Note
dated November 1, 2006, executed by US Bio Woodbury, LLC
|
|
10
|
.22
|
|
Allonge (Term Revolving Note) dated October 19, 2007 to the Term
Revolving Note dated November 1, 2006, executed by US Bio
Woodbury, LLC.
|
|
10
|
.23
|
|
Change in Control Agreement dated as of September 28, 2007
between US BioEnergy Corporation and Gordon W. Ommen.
|
|
10
|
.24
|
|
Change in Control Agreement dated as of September 28, 2007
between US BioEnergy Corporation and each of Richard Atkinson,
Gregory S. Schlicht, Chad Hatch and Kim Regenhard.
|
|
31
|
.1
|
|
Certification of Chief Executive Officer pursuant to
Section 302 of the Sarbanes-Oxley Act of 2002
|
|
31
|
.2
|
|
Certification of Chief Financial Officer pursuant to
Section 302 of the Sarbanes-Oxley Act of 2002
|
|
32
|
.1
|
|
Certification of Chief Executive Officer pursuant to
18 U.S.C. Section 1350, as adopted pursuant to
Section 906 of the Sarbanes-Oxley Act of 2002
|
|
32
|
.2
|
|
Certification of Chief Financial Officer pursuant to
18 U.S.C. Section 1350, as adopted pursuant to
Section 906 of the Sarbanes-Oxley Act of 2002
|
56
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.
|
|
|
|
|
US BIOENERGY CORPORATION
|
|
|
|
|
|
|
|
|
|
Date: November 13, 2007
|
|
By:
/s/ Gordon
W. Ommen
Gordon
W. Ommen
Chief Executive Officer and President
(Principal Executive Officer)
|
|
|
|
|
|
|
|
|
|
Date: November 13, 2007
|
|
By:
/s/ Richard
K. Atkinson
Richard
K. Atkinson
Senior Vice President and
Chief Financial Officer
(Principal Financial Officer)
|
57
|
|
|
|
|
Exhibit No.
|
|
Description
|
|
|
10
|
.1
|
|
Lease Agreement, dated July 10, 2007, between CHS, Inc. and
US BioEnergy Corporation (incorporated by reference to
Exhibit 10.1 to US BioEnergys
Form 8-K,
filed with the SEC on July 10, 2007, File
No. 001-33203)
|
|
10
|
.2
|
|
Amendment No. 1 to Fourth Supplement to the Master Loan
Agreement (Term Revolving Loan) dated October 19, 2007 by and
between US Bio Woodbury, LLC and AgStar Financial Services, PCA.
|
|
10
|
.3
|
|
Amendment No. 1 To the Credit Agreement dated October 19, 2007
by and between US Bio Ord, LLC and AgStar Financial Services,
PCA.
|
|
10
|
.4
|
|
Amendment No. 1 To the Credit Agreement dated October 19, 2007
by and between US Bio Hankinson, LLC and AgStar Financial
Services, PCA.
|
|
10
|
.5
|
|
Amendment No. 1 To the Credit Agreement dated October 19, 2007
by and between US Bio Janesville, LLC and AgStar Financial
Services, PCA.
|
|
10
|
.6
|
|
Amendment No. 1 To the Credit Agreement dated October 19, 2007
by and between US Bio Dyersville, LLC and AgStar Financial
Services, PCA.
|
|
10
|
.7
|
|
Amendment No. 1 To the Credit Agreement dated October 19, 2007
by and between US Bio Platte Valley, LLC and AgStar Financial
Services, PCA.
|
|
10
|
.8
|
|
Amendment No. 2 To the Credit Agreement dated November 1, 2007
by and between US Bio Dyersville, LLC and AgStar Financial
Services, PCA.
|
|
10
|
.9
|
|
Amendment No. 2 To the Amended and Restated Master Loan
Agreement dated November 1, 2007 by and between US Bio Albert
City, LLC and AgStar Financial Services, PCA.
|
|
10
|
.10
|
|
Amendment No. 1 To the Amended and Restated Master Loan
Agreement dated as of October 19, 2007 by and between US Bio
Albert City, LLC and AgStar Financial Services, PCA.
|
|
10
|
.11
|
|
Amendment No. 1 to Second Supplement to the Master Loan
Agreement (Revolving Loan) dated as of October 19, 2007 by and
between US Bio Albert City, LLC and AgStar Financial Services,
PCA.
|
|
10
|
.12
|
|
Amendment No. 1 to Third Supplement to the Master Loan Agreement
(Term Loan) dated as of October 19, 2007 by and between US Bio
Albert City, LLC and AgStar Financial Services, PCA.
|
|
10
|
.13
|
|
Allonge (Term Note) dated as of October 19, 2007 to the Term
Note dated February 26, 2007, executed by US Bio Albert City,
LLC.
|
|
10
|
.14
|
|
Amendment No. 1 to Fourth Supplement to the Master Loan
Agreement (Term Revolving Loan) dated as of October 19, 2007 by
and between US Bio Albert City, LLC and AgStar Financial
Services, PCA.
|
|
10
|
.15
|
|
Allonge dated as of October 19, 2007 to the Term Revolving Note
dated February 26, 2007 executed by US Bio Albert City, LLC.
|
|
10
|
.16
|
|
Amendment No. 2 to Amended and Restated Second Supplement
to the Master Loan Agreement (Revolving Loan) dated
November 1, 2007, by and between US Bio Woodbury, LLC and
AgStar Financial Services, PCA.
|
|
10
|
.17
|
|
Allonge to Amended and Restated Revolving Note dated
November 1, 2007, executed by US Bio Woodbury, LLC.
|
|
10
|
.18
|
|
Amendment No. 2 to Master Loan Agreement dated October 19, 2007,
by and between US Bio Woodbury, LLC and AgStar Financial
Services, PCA.
|
|
10
|
.19
|
|
Amendment No. 1 to Amended and Restated Second Supplement to the
Master Loan Agreement (Revolving Loan) dated October 19, 2007 by
and between US Bio Woodbury, LLC and AgStar Financial Services,
PCA.
|
|
10
|
.20
|
|
Amendment No. 1 to Third Supplement to the Master Loan Agreement
(Term Loan) dated October 19, 2007 by and between US Bio
Woodbury, LLC and AgStar Financial Services, PCA.
|
|
10
|
.21
|
|
Allonge (Term Note) dated October 19, 2007 to the Term Note
dated November 1, 2006, executed by US Bio Woodbury, LLC
|
|
10
|
.22
|
|
Allonge (Term Revolving Note) dated October 19, 2007 to the Term
Revolving Note dated November 1, 2006, executed by US Bio
Woodbury, LLC.
|
58
|
|
|
|
|
Exhibit No.
|
|
Description
|
|
|
10
|
.23
|
|
Change in Control Agreement dated as of September 28, 2007
between US BioEnergy Corporation and Gordon W. Ommen.
|
|
10
|
.24
|
|
Change in Control Agreement dated as of September 28, 2007
between US BioEnergy Corporation and each of Richard Atkinson,
Gregory S. Schlicht, Chad Hatch and Kim Regenhard.
|
|
31
|
.1
|
|
Certification of Chief Executive Officer pursuant to
Section 302 of the Sarbanes-Oxley Act of 2002
|
|
31
|
.2
|
|
Certification of Chief Financial Officer pursuant to
Section 302 of the Sarbanes-Oxley Act of 2002
|
|
32
|
.1
|
|
Certification of Chief Executive Officer pursuant to
18 U.S.C. Section 1350, as adopted pursuant to
Section 906 of the Sarbanes-Oxley Act of 2002
|
|
32
|
.2
|
|
Certification of Chief Financial Officer pursuant to
18 U.S.C. Section 1350, as adopted pursuant to
Section 906 of the Sarbanes-Oxley Act of 2002
|
59
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