b795d5b95e754d5

 

 

 

 

 

                                                                                                             

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington,  D.C. 20549 

______________________

 

FORM 10-Q

 

Quarterly Report Pursuant to Section 13 or 15(d) of the
Securities Exchange Act of 1934

 

For the Quarterly Period Ended September 30, 2012

 

Commission File Number 001-32924

 

Green Plains Renewable Energy, Inc.

(Exact name of registrant as specified in its charter)

 

 

 

Iowa

84-1652107

(State or other jurisdiction of incorporation or organization)

(I.R.S. Employer Identification No.)

 

 

450 Regency Parkway, Suite 400, Omaha, NE 68114

(402) 884-8700

(Address of principal executive offices, including zip code)

(Registrant’s telephone number, including area code)

 

 

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

 

S Yes   £ No

 

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

S Yes   £ No

 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

 

Large accelerated filer             £      Accelerated filer T      Non-accelerated filer £     Smaller reporting company £

 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). 

 

£ Yes   S No

 

The number of shares of common stock, par value $0.001 per share, outstanding as of October 30,  2012 was 29,678,413 shares.

 

 


 

 

TABLE OF CONTENTS

 

 

 

 

 

Page

PART I – FINANCIAL INFORMATION

 

 

 

Item 1.

Financial Statements

 

 

 

 

 

Consolidated Balance Sheets 

2

 

 

 

 

Consolidated Statements of Operations

3

 

 

 

 

Consolidated Statements of Comprehensive Income

4

 

 

 

 

Consolidated Statements of Cash Flows 

5

 

 

 

 

Notes to Consolidated Financial Statements 

7

 

 

 

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

25

 

 

 

Item 3.

Quantitative and Qualitative Disclosures About Market Risk 

40

 

 

 

Item 4.

Controls and Procedures

42

 

 

 

 

 

 

PART II – OTHER INFORMATION

 

 

 

 

Item 1.

Legal Proceedings

43

 

 

 

Item 1A.

Risk Factors

43

 

 

 

Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds

45

 

 

 

Item 3.

Defaults Upon Senior Securities

46

 

 

 

Item 4.

Mine Safety Disclosures

46

 

 

 

Item 5.

Other Information

46

 

 

 

Item 6.

Exhibits

47

 

 

 

Signatures 

48

 

 

 

 

1

 


 

 

GREEN PLAINS RENEWABLE ENERGY, INC. AND SUBSIDIARIES

 

 CONSOLIDATED BALANCE SHEETS

 

(in thousands, except share amounts)

 

 

 

 

 

 

 

 

 

 

September 30,

 

December 31,

 

2012

 

2011

 

(unaudited)

 

 

 

ASSETS

Current assets

 

 

 

 

 

Cash and cash equivalents

$

140,177 

 

$

174,988 

Restricted cash

 

19,573 

 

 

19,619 

Accounts receivable, net of allowances of $488 and $263, respectively

 

102,565 

 

 

106,198 

Inventories

 

241,230 

 

 

229,070 

Prepaid expenses and other

 

15,344 

 

 

14,289 

Deferred income taxes

 

23,030 

 

 

14,828 

Derivative financial instruments

 

42,759 

 

 

17,428 

Total current assets

 

584,678 

 

 

576,420 

Property and equipment, net of accumulated depreciation of

 

 

 

 

 

$165,132 and $125,798, respectively

 

761,276 

 

 

776,789 

Goodwill

 

40,877 

 

 

40,877 

Other assets

 

29,703 

 

 

26,742 

Total assets

$

1,416,534 

 

$

1,420,828 

 

 

 

 

 

 

LIABILITIES AND STOCKHOLDERS' EQUITY

Current liabilities

 

 

 

 

 

Accounts payable

$

147,426 

 

$

172,328 

Accrued and other liabilities

 

33,508 

 

 

29,825 

Unearned revenue

 

4,302 

 

 

15,453 

Short-term notes payable and other borrowings

 

157,914 

 

 

69,599 

Current maturities of long-term debt

 

73,092 

 

 

73,760 

Total current liabilities

 

416,242 

 

 

360,965 

 

 

 

 

 

 

Long-term debt

 

457,991 

 

 

493,407 

Deferred income taxes

 

64,913 

 

 

55,970 

Other liabilities

 

5,069 

 

 

5,129 

Total liabilities

 

944,215 

 

 

915,471 

 

 

 

 

 

 

Stockholders' equity

 

 

 

 

 

Common stock, $0.001 par value; 75,000,000 shares authorized;

 

 

 

 

 

36,854,628 and 36,413,611 shares issued, and 29,654,628

 

 

 

 

 

and 32,913,611 shares outstanding, respectively

 

37 

 

 

36 

Additional paid-in capital

 

443,746 

 

 

440,469 

Retained earnings

 

74,517 

 

 

95,761 

Accumulated other comprehensive income (loss)

 

19,595 

 

 

(2,953)

Treasury stock, 7,200,000 and 3,500,000 shares, respectively

 

(65,808)

 

 

(28,201)

Total Green Plains stockholders' equity

 

472,087 

 

 

505,112 

Noncontrolling interests

 

232 

 

 

245 

Total stockholders' equity

 

472,319 

 

 

505,357 

Total liabilities and stockholders' equity

$

1,416,534 

 

$

1,420,828 

 

See accompanying notes to the consolidated financial statements.

 

 

2

 


 

 

GREEN PLAINS RENEWABLE ENERGY, INC. AND SUBSIDIARIES

 

CONSOLIDATED STATEMENTS OF OPERATIONS

 

(unaudited and in thousands, except per share amounts)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended
September 30,

 

Nine Months Ended
September 30,

 

2012

 

2011

 

2012

 

2011

 

 

 

 

 

 

 

 

 

 

 

 

Revenues

$

947,413 

 

$

957,018 

 

$

2,593,163 

 

$

2,630,921 

Cost of goods sold

 

919,516 

 

 

909,725 

 

 

2,538,363 

 

 

2,510,742 

Gross profit

 

27,897 

 

 

47,293 

 

 

54,800 

 

 

120,179 

Selling, general and administrative expenses

 

19,273 

 

 

18,248 

 

 

58,350 

 

 

53,350 

Operating income (loss)

 

8,624 

 

 

29,045 

 

 

(3,550)

 

 

66,829 

Other income (expense)

 

 

 

 

 

 

 

 

 

 

 

Interest income

 

46 

 

 

59 

 

 

144 

 

 

222 

Interest expense

 

(9,832)

 

 

(9,440)

 

 

(28,741)

 

 

(27,438)

Other, net

 

(448)

 

 

(284)

 

 

(1,859)

 

 

(470)

Total other expense

 

(10,234)

 

 

(9,665)

 

 

(30,456)

 

 

(27,686)

Income (loss) before income taxes

 

(1,610)

 

 

19,380 

 

 

(34,006)

 

 

39,143 

Income tax expense (benefit)

 

(604)

 

 

6,979 

 

 

(12,749)

 

 

14,191 

Net income (loss)

 

(1,006)

 

 

12,401 

 

 

(21,257)

 

 

24,952 

Net loss attributable to noncontrolling interests

 

 

 

28 

 

 

13 

 

 

200 

Net income (loss) attributable to Green Plains

$

(1,002)

 

$

12,429 

 

$

(21,244)

 

$

25,152 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings per share:

 

 

 

 

 

 

 

 

 

 

 

Income (loss) attributable to Green Plains stockholders - basic

$

(0.03)

 

$

0.35 

 

$

(0.70)

 

$

0.70 

Income (loss) attributable to Green Plains stockholders - diluted

$

(0.03)

 

$

0.32 

 

$

(0.70)

 

$

0.66 

Weighted average shares outstanding:

 

 

 

 

 

 

 

 

 

 

 

Basic

 

29,655 

 

 

35,624 

 

 

30,499 

 

 

36,075 

Diluted

 

29,655 

 

 

42,151 

 

 

30,499 

 

 

42,611 

 

 

 

 

 

 

 

 

 

See accompanying notes to the consolidated financial statements.

3

 


 

 

GREEN PLAINS RENEWABLE ENERGY, INC. AND SUBSIDIARIES

 

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

 

(unaudited and in thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended
September 30,

 

Nine Months Ended
September 30,

 

2012

 

2011

 

2012

 

2011

 

 

 

 

 

 

 

 

 

 

 

 

Net income (loss)

$

(1,006)

 

$

12,401 

 

$

(21,257)

 

$

24,952 

Other comprehensive income (loss):

 

 

 

 

 

 

 

 

 

 

 

Unrealized gains (losses) on derivatives arising during period

 

26,497 

 

 

(16,806)

 

 

45,538 

 

 

(33,031)

Reclassification of realized (gains) losses on derivatives

 

(11,297)

 

 

14,950 

 

 

(9,502)

 

 

22,448 

Income tax (expense) benefit related to other comprehensive income (loss)

 

(5,712)

 

 

683 

 

 

(13,488)

 

 

4,052 

Other comprehensive income (loss)

 

9,488 

 

 

(1,173)

 

 

22,548 

 

 

(6,531)

Comprehensive income

 

8,482 

 

 

11,228 

 

 

1,291 

 

 

18,421 

Comprehensive loss attributable to noncontrolling interests

 

 

 

28 

 

 

13 

 

 

200 

Comprehensive income attributable to Green Plains

$

8,486 

 

$

11,256 

 

$

1,304 

 

$

18,621 

 

 

See accompanying notes to the consolidated financial statements.

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

4

 


 

 

GREEN PLAINS RENEWABLE ENERGY, INC. AND SUBSIDIARIES

 

CONSOLIDATED STATEMENTS OF CASH FLOWS

 

(unaudited and in thousands)

 

 

 

 

 

 

 

 

 

 

 

Nine Months Ended
September 30,

 

2012

 

2011

Cash flows from operating activities:

 

 

 

 

 

Net income (loss)

$

(21,257)

 

$

24,952 

Adjustments to reconcile net income (loss) to net cash

 

 

 

 

 

provided (used) by operating activities:

 

 

 

 

 

Depreciation and amortization

 

39,922 

 

 

36,848 

Amortization of debt issuance costs

 

2,314 

 

 

1,703 

Deferred income taxes

 

741 

 

 

10,467 

Stock-based compensation expense

 

3,149 

 

 

2,743 

Undistributed equity in loss of affiliates

 

1,858 

 

 

470 

Allowance for doubtful accounts

 

225 

 

 

122 

Other

 

1,922 

 

 

 -

Changes in operating assets and liabilities before

 

 

 

 

 

effects of business combinations:

 

 

 

 

 

Accounts receivable

 

3,492 

 

 

(31,949)

Inventories

 

(11,297)

 

 

7,210 

Derivative financial instruments

 

(2,858)

 

 

(16,543)

Prepaid expenses and other assets

 

(971)

 

 

(2,324)

Accounts payable and accrued liabilities

 

(21,319)

 

 

(5,994)

Unearned revenues

 

(11,151)

 

 

(12,307)

Other

 

(270)

 

 

550 

Net cash provided (used) by operating activities

 

(15,500)

 

 

15,948 

 

 

 

 

 

 

Cash flows from investing activities:

 

 

 

 

 

Purchases of property and equipment

 

(23,892)

 

 

(35,526)

Acquisition of businesses, net of cash acquired

 

(1,490)

 

 

(8,115)

Other

 

(6,513)

 

 

(1,124)

Net cash used by investing activities

 

(31,895)

 

 

(44,765)

 

 

 

 

 

 

Cash flows from financing activities:

 

 

 

 

 

Proceeds from the issuance of long-term debt

 

53,200 

 

 

110,088 

Payments of principal on long-term debt

 

(87,690)

 

 

(160,732)

Proceeds from short-term borrowings

 

2,457,848 

 

 

2,640,404 

Payments on short-term borrowings

 

(2,400,211)

 

 

(2,648,963)

Payments for repurchase of common stock

 

(10,445)

 

 

(14,201)

Change in restricted cash

 

46 

 

 

(8,724)

Payments of loan fees

 

(306)

 

 

(1,702)

Other

 

142 

 

 

(2,630)

Net cash provided (used) by financing activities

 

12,584 

 

 

(86,460)

 

 

 

 

 

 

Net change in cash and cash equivalents

 

(34,811)

 

 

(115,277)

Cash and cash equivalents, beginning of period

 

174,988 

 

 

233,205 

Cash and cash equivalents, end of period

$

140,177 

 

$

117,928 

 

 

 

 

 

 

Continued on the following page

 

 

 

 

 

 

 

 

5

 


 

 

 

 

 

 

GREEN PLAINS RENEWABLE ENERGY, INC. AND SUBSIDIARIES

 

CONSOLIDATED STATEMENTS OF CASH FLOWS

 

(unaudited and in thousands)

 

 

 

 

 

 

 

 

 

 

Continued from the previous page

 

 

 

 

 

 

Nine Months Ended
September 30,

 

2012

 

2011

 

 

 

 

 

 

Supplemental disclosures of cash flow:

 

 

 

 

 

Cash paid for income taxes

$

495 

 

$

955 

Cash paid for interest

$

24,479 

 

$

26,078 

 

 

 

 

 

 

Supplemental noncash investing and financing activities:

 

 

 

 

 

Assets acquired in acquisitions and mergers

$

1,590 

 

$

62,686 

Less: liabilities assumed

 

(100)

 

 

(54,571)

Net assets acquired

$

1,490 

 

$

8,115 

 

 

 

 

 

 

Short-term note payable issued to repurchase common stock

$

27,162 

 

$

14,000 

 

 

 

See accompanying notes to the consolidated financial statements.

6

 


 

 

GREEN PLAINS RENEWABLE ENERGY, INC. AND SUBSIDIARIES

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

 

(unaudited)

 

1.  BASIS OF PRESENTATION, DESCRIPTION OF BUSINESS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

 

References to the Company

 

References to “Green Plains” or the “Company” in the consolidated financial statements and in these notes to the consolidated financial statements refer to Green Plains Renewable Energy, Inc., an Iowa corporation, and its subsidiaries.

 

Consolidated Financial Statements

 

The consolidated financial statements include the accounts of the Company, its wholly-owned subsidiaries and entities which it controls. All significant intercompany balances and transactions have been eliminated on a consolidated basis for reporting purposes. Unconsolidated entities are included in the financial statements on an equity basis. Results for the interim periods presented are not necessarily indicative of results to be expected for the entire year.

 

The accompanying unaudited consolidated financial statements have been prepared in conformity with U.S. generally accepted accounting principles, or GAAP, for interim financial information and the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. The financial statements should be read in conjunction with the Company’s annual report on Form 10-K for the year ended December 31, 2011.

 

The unaudited financial information reflects all adjustments which are, in the opinion of management, necessary for a fair presentation of the results of operations, financial position and cash flows for the periods presented. The adjustments are of a normal recurring nature, except as otherwise noted.

 

Use of Estimates in the Preparation of Consolidated Financial Statements

 

The preparation of consolidated financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

 

Description of Business

 

Green Plains is North America’s fourth largest ethanol producer. The Company operates nine ethanol plants with approximately 740 million gallons per year, or mmgy, of total ethanol production capacity. The Company’s in-house marketing business is responsible for the sales, marketing and distribution of all ethanol, distillers grains and corn oil produced at its nine ethanol plants. The Company also markets and distributes ethanol for third-party ethanol producers.  Additionally, the Company owns and operates grain handling and storage assets and provides complementary agronomy services to local grain producers through its agribusiness segment. The Company owns and operates nine blending and terminaling facilities with approximately 625 mmgy of total throughput capacity. The Company is a partner in a joint venture that was formed to commercialize advanced photo-bioreactor technologies for growing and harvesting of algal biomass.

 

Revenue Recognition

 

The Company recognizes revenue when all of the following criteria are satisfied: persuasive evidence of an arrangement exists; risk of loss and title transfer to the customer; the price is fixed and determinable; and collectability is reasonably assured.

 

For sales of ethanol, distillers grains and other commodities by the Company’s marketing business, revenue is recognized when title to the product and risk of loss transfer to an external customer. Revenues related to marketing operations for third parties are recorded on a gross basis as the Company takes title to the product and assumes risk of loss. Unearned revenue is reflected on the consolidated balance sheets for goods in transit for which the Company has received payment and title has not been transferred to the customer. Revenues from the Company’s biofuel terminal operations, which include ethanol transload and splash blending services, are recognized as these services are rendered.

7

 


 

 

 

The Company routinely enters into fixed-price, physical-delivery ethanol sales agreements. In certain instances, the Company intends to settle the transaction by open market purchases of ethanol rather than by delivery from its own production. These transactions are reported net as a component of revenues. Revenues also include realized gains and losses on related derivative financial instruments, ineffectiveness on cash flow hedges, and reclassifications of realized gains and losses on effective cash flow hedges from accumulated other comprehensive income (loss).

 

Sales of agricultural commodities, fertilizers and other similar products are recognized when title to the product and risk of loss transfer to the customer, which is dependent on the agreed upon sales terms with the customer. These sales terms provide for passage of title either at the time shipment is made or at the time the commodity has been delivered to its destination and final weights, grades and settlement prices have been agreed upon with the customer. Revenues related to grain merchandising are presented gross in the statements of operations with amounts billed for shipping and handling included in revenues and also as a component of cost of goods sold. Revenues from grain storage are recognized as services are rendered.

 

Cost of Goods Sold

 

Cost of goods sold includes costs for direct labor, materials and certain plant overhead costs. Direct labor includes all compensation and related benefits of non-management personnel involved in the operation of the Company’s ethanol plants. Grain purchasing and receiving costs, other than labor costs for grain buyers and scale operators, are also included in cost of goods sold. Direct materials consist of the costs of corn feedstock, denaturant, and process chemicals. Corn feedstock costs include unrealized gains and losses on related derivative financial instruments not designated as cash flow hedges, inbound freight charges, inspection costs and transfer costs. Corn feedstock costs also include realized gains and losses on related derivative financial instruments, ineffectiveness on cash flow hedges, and reclassifications of realized gains and losses on effective cash flow hedges from accumulated other comprehensive income (loss). Plant overhead costs primarily consist of plant utilities, plant depreciation and outbound freight charges. Shipping costs incurred directly by the Company, including railcar lease costs, are also reflected in cost of goods sold.

 

The Company uses exchange-traded futures and options contracts to minimize the effects of changes in the prices of agricultural commodities on its agribusiness segment’s grain inventories and forward purchase and sales contracts. Exchange-traded futures and options contracts are valued at quoted market prices. Grain inventories, forward purchase contracts and forward sale contracts in the agribusiness segment are valued at market prices, where available, or other market quotes adjusted for differences, primarily transportation, between the exchange-traded market and the local markets on which the terms of the contracts are based. Changes in the fair value of grain inventories, forward purchase and sale contracts, and exchange-traded futures and options contracts in the agribusiness segment, are recognized in earnings as a component of cost of goods sold. These contracts are predominantly settled in cash. The Company is exposed to loss in the event of non-performance by the counter-party to forward purchase and forward sales contracts.

 

Derivative Financial Instruments

 

To minimize the risk and the effects of the volatility of commodity price changes primarily related to corn, ethanol and natural gas, the Company uses various derivative financial instruments, including exchange-traded futures, and exchange-traded and over-the-counter options contracts. The Company monitors and manages this exposure as part of its overall risk management policy. As such, the Company seeks to reduce the potentially adverse effects that the volatility of these markets may have on its operating results. The Company may take hedging positions in these commodities as one way to mitigate risk. While the Company attempts to link its hedging activities to purchase and sales activities, there are situations in which these hedging activities can themselves result in losses.

 

By using derivatives to hedge exposures to changes in commodity prices, the Company has exposures on these derivatives to credit and market risk. The Company is exposed to credit risk that the counterparty might fail to fulfill its performance obligations under the terms of the derivative contract. The Company minimizes its credit risk by entering into transactions with high quality counterparties, limiting the amount of financial exposure it has with each counterparty and monitoring the financial condition of its counterparties. Market risk is the risk that the value of the financial instrument might be adversely affected by a change in commodity prices or interest rates. The Company manages market risk by incorporating monitoring parameters within its risk management strategy that limit the types of derivative instruments and derivative strategies the Company uses, and the degree of market risk that may be undertaken by the use of derivative instruments.

 

The Company evaluates its contracts that involve physical delivery to determine whether they may qualify for the normal purchases or normal sales exemption and are expected to be used or sold over a reasonable period in the normal course of

8

 


 

 

business. Any contracts that do not meet the normal purchase or sales criteria are recorded at fair value with the change in fair value recorded in operating income unless the contracts qualify for, and the Company elects, hedge accounting treatment.

 

Certain qualifying derivatives within the ethanol production segment are designated as cash flow hedges. Prior to entering into cash flow hedges, the Company evaluates the derivative instrument to ascertain its effectiveness. For cash flow hedges, any ineffectiveness is recognized in current period results, while other unrealized gains and losses are reflected in accumulated other comprehensive income until gains and losses from the underlying hedged transaction are realized. In the event that it becomes probable that a forecasted transaction will not occur, the Company would discontinue cash flow hedge treatment, which would affect earnings. These derivative financial instruments are recognized in current assets or other current liabilities at fair value.

 

At times, the Company hedges its exposures to changes in the value of inventories and designates certain qualifying derivatives as fair value hedges. The carrying amount of the hedged inventory is adjusted through current period results for changes in the fair value arising from changes in underlying prices. Any ineffectiveness is recognized in current period results to the extent that the change in the fair value of the inventory is not offset by the change in the fair value of the derivative.

 

Recent Accounting Pronouncements

 

Effective January 1, 2012, the Company adopted the third phase of amended guidance in ASC Topic 820, Fair Value Measurements and Disclosures. The amended guidance clarifies the application of existing fair value measurement requirements and requires additional disclosure for Level 3 measurements regarding the sensitivity of fair value to changes in unobservable inputs and any interrelationships between those inputs. The Company currently is not impacted by the additional disclosure requirements as it does not have any recurring Level 3 measurements.

 

Effective January 1, 2012, the Company adopted the amended guidance in ASC Topic 220, Comprehensive Income. This accounting standards update is aimed at increasing the prominence of other comprehensive income in the financial statements by eliminating the option to present other comprehensive income in the statement of stockholders’ equity. The Company has elected to present net income and other comprehensive income in two separate but consecutive statements. The updated presentation, which has been implemented retroactively for all comparable periods presented, did not impact the Company’s financial position or results of operations.

 

            Effective January 1, 2012, the Company adopted the amended guidance in ASC Topic 350, Intangibles – Goodwill and Other. The amended guidance permits an entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether it is necessary to perform the two-step goodwill impairment test. The amended guidance did not impact the Company’s disclosure or reporting requirements.

 

2.  FAIR VALUE DISCLOSURES

 

The following methods, assumptions and valuation techniques were used in estimating the fair value of the Company’s financial instruments:

 

Level 1 – unadjusted quoted prices in active markets for identical assets or liabilities that the Company has the ability to access at the measurement date. Level 1 unrealized gains and losses on commodity derivatives relate to exchange-traded open trade equity and option values in the Company’s brokerage accounts.

 

Level 2 – directly or indirectly observable inputs such as quoted prices for similar assets or liabilities in active markets other than quoted prices included within Level 1; quoted prices for identical or similar assets in markets that are not active; and other inputs that are observable or can be substantially corroborated by observable market data by correlation or other means. Grain inventories held for sale in the agribusiness segment are valued at nearby futures values, plus or minus nearby basis levels.

 

Level 3 – unobservable inputs that are supported by little or no market activity and that are a significant component of the fair value of the assets or liabilities. The Company currently does not have any recurring Level 3 financial instruments.

9

 


 

 

There have been no changes in valuation techniques and inputs used in measuring fair value. The following tables set forth the Company’s assets and liabilities by level that were accounted for the periods indicated (in thousands):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Fair Value Measurements at September 30, 2012

 

Quoted Prices in Active Markets for Identical Assets

 

Significant Other Observable Inputs

 

Reclassification for Balance Sheet

 

 

 

 

(Level 1)

 

(Level 2)

 

Presentation

 

Total

Assets:

 

 

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

$

140,177 

 

$

 -

 

$

 -

 

$

140,177 

Restricted cash

 

21,773 

 

 

 -

 

 

 -

 

 

21,773 

Margin deposits

 

16,924 

 

 

 -

 

 

(16,924)

 

 

 -

Inventories carried at market

 

 -

 

 

123,376 

 

 

 -

 

 

123,376 

Unrealized gains on derivatives

 

12,787 

 

 

22,027 

 

 

8,116 

 

 

42,930 

Total assets measured at fair value

$

191,661 

 

$

145,403 

 

$

(8,808)

 

$

328,256 

 

 

 

 

 

 

 

 

 

 

 

 

Liabilities:

 

 

 

 

 

 

 

 

 

 

 

Unrealized losses on derivatives

$

8,875 

 

$

15,129 

 

$

(8,808)

 

$

15,196 

Inventory financing arrangements

 

 -

 

 

16,237 

 

 

 -

 

 

16,237 

Other

 

70 

 

 

 -

 

 

 -

 

 

70 

Total liabilities measured at fair value

$

8,945 

 

$

31,366 

 

$

(8,808)

 

$

31,503 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Fair Value Measurements at December 31, 2011

 

Quoted Prices in Active Markets for Identical Assets

 

Significant Other Observable Inputs

 

Reclassification for Balance Sheet

 

 

 

 

(Level 1)

 

(Level 2)

 

Presentation

 

Total

Assets:

 

 

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

$

174,988 

 

$

 -

 

$

 -

 

$

174,988 

Restricted cash

 

21,820 

 

 

 -

 

 

 -

 

 

21,820 

Inventories carried at market

 

 -

 

 

112,948 

 

 

 -

 

 

112,948 

Unrealized gains on derivatives

 

15,710 

 

 

6,010 

 

 

(4,292)

 

 

17,428 

Total assets measured at fair value

$

212,518 

 

$

118,958 

 

$

(4,292)

 

$

327,184 

 

 

 

 

 

 

 

 

 

 

 

 

Liabilities:

 

 

 

 

 

 

 

 

 

 

 

Unrealized losses on derivatives

$

2,828 

 

$

5,287 

 

$

(2,698)

 

$

5,417 

Margin deposits

 

1,594 

 

 

 -

 

 

(1,594)

 

 

 -

Inventory financing arrangements

 

 -

 

 

8,894 

 

 

 -

 

 

8,894 

Other

 

71 

 

 

 -

 

 

 -

 

 

71 

Total liabilities measured at fair value

$

4,493 

 

$

14,181 

 

$

(4,292)

 

$

14,382 

 

The Company believes the fair values of its debt, accounts receivable and accounts payable approximate book value, which were  $689.0 million $102.6 million and $147.4 million, respectively, at September 30, 2012 and $636.8 million $106.2 million and $172.3 million, respectively, at December 31, 2011.

 

            Although the Company currently does not have any Level 3 financial measurements, the fair values of the tangible assets and goodwill acquired in previous reporting periods represent Level 3 measurements and were derived using a combination of the income approach, the market approach and the cost approach as considered appropriate for the specific assets being valued.

 

 

10

 


 

 

3.  SEGMENT INFORMATION

 

Company management reviews financial and operating performance in the following four separate operating segments: (1) production of ethanol and distillers grains, collectively referred to as ethanol production, (2) corn oil production, (3) grain warehousing and marketing, as well as sales and related services of agronomy and petroleum products, collectively referred to as agribusiness, and (4) marketing and logistics services for Company-produced and third-party ethanol, distillers grains, corn oil and other commodities, and the operation of blending and terminaling facilities, collectively referred to as marketing and distribution. Selling, general and administrative expenses, primarily consisting of compensation of corporate employees, professional fees and overhead costs not directly related to a specific operating segment, are reflected in the table below as corporate activities.

 

During the normal course of business, the Company enters into transactions between segments. Examples of these intersegment transactions include, but are not limited to, the ethanol production segment selling ethanol to the marketing and distribution segment and the agribusiness segment selling grain to the ethanol production segment. These intersegment activities are recorded by each segment at prices approximating market and treated as if they are third-party transactions. Consequently, these transactions impact segment performance. However, revenues and corresponding costs are eliminated in consolidation and do not impact the Company’s consolidated results.

 

The following are certain financial data for the Company’s operating segments for the periods indicated (in thousands):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended
September 30,

 

Nine Months Ended
September 30,

 

 

2012

 

2011

 

2012

 

2011

Revenues:

 

 

 

 

 

 

 

 

 

 

 

 

Ethanol production:

 

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

$

52,982 

 

$

35,077 

 

$

149,115 

 

$

97,377 

Intersegment revenues

 

 

439,917 

 

 

551,987 

 

 

1,268,851 

 

 

1,501,031 

Total segment revenues

 

 

492,899 

 

 

587,064 

 

 

1,417,966 

 

 

1,598,408 

Corn oil production:

 

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

 

 

 

393 

 

 

518 

 

 

1,464 

Intersegment revenues

 

 

14,530 

 

 

15,115 

 

 

43,003 

 

 

28,886 

Total segment revenues

 

 

14,531 

 

 

15,508 

 

 

43,521 

 

 

30,350 

Agribusiness:

 

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

 

125,446 

 

 

95,065 

 

 

300,051 

 

 

233,959 

Intersegment revenues

 

 

50,254 

 

 

48,863 

 

 

134,725 

 

 

149,676 

Total segment revenues

 

 

175,700 

 

 

143,928 

 

 

434,776 

 

 

383,635 

Marketing and distribution:

 

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

 

768,984 

 

 

826,483 

 

 

2,143,479 

 

 

2,298,121 

Intersegment revenues

 

 

111 

 

 

98 

 

 

302 

 

 

375 

Total segment revenues

 

 

769,095 

 

 

826,581 

 

 

2,143,781 

 

 

2,298,496 

Revenues including intersegment activity

 

 

1,452,225 

 

 

1,573,081 

 

 

4,040,044 

 

 

4,310,889 

Intersegment eliminations

 

 

(504,812)

 

 

(616,063)

 

 

(1,446,881)

 

 

(1,679,968)

Revenues as reported

 

$

947,413 

 

$

957,018 

 

$

2,593,163 

 

$

2,630,921 

 

11

 


 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

September 30,

 

Nine Months Ended

September 30,

 

 

2012

 

2011

 

2012

 

2011

Gross profit (loss):

 

 

 

 

 

 

 

 

 

 

 

 

Ethanol production

 

$

(3,701)

 

$

24,846 

 

$

(20,610)

 

$

63,880 

Corn oil production

 

 

7,865 

 

 

9,642 

 

 

25,205 

 

 

18,098 

Agribusiness

 

 

12,513 

 

 

8,223 

 

 

27,357 

 

 

20,425 

Marketing and distribution

 

 

10,980 

 

 

5,069 

 

 

21,769 

 

 

17,332 

Intersegment eliminations

 

 

240 

 

 

(487)

 

 

1,079 

 

 

444 

 

 

$

27,897 

 

$

47,293 

 

$

54,800 

 

$

120,179 

Operating income (loss):

 

 

 

 

 

 

 

 

 

 

 

 

Ethanol production

 

$

(7,520)

 

$

20,941 

 

$

(32,435)

 

$

52,184 

Corn oil production

 

 

7,811 

 

 

9,632 

 

 

25,011 

 

 

18,040 

Agribusiness

 

 

5,849 

 

 

2,151 

 

 

8,916 

 

 

3,934 

Marketing and distribution

 

 

7,162 

 

 

1,923 

 

 

10,546 

 

 

7,078 

Intersegment eliminations

 

 

240 

 

 

(481)

 

 

1,113 

 

 

474 

Corporate activities

 

 

(4,918)

 

 

(5,121)

 

 

(16,701)

 

 

(14,881)

 

 

$

8,624 

 

$

29,045 

 

$

(3,550)

 

$

66,829 

 

The following table sets forth revenues by product line for the periods indicated (in thousands):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended
September 30,

 

Nine Months Ended
September 30,

 

 

2012

 

2011

 

2012

 

2011

Revenues:

 

 

 

 

 

 

 

 

 

 

 

 

Ethanol

 

$

672,177 

 

$

732,061 

 

$

1,887,376 

 

$

2,050,683 

Corn oil

 

 

15,255 

 

 

15,508 

 

 

44,041 

 

 

30,350 

Distillers grains

 

 

111,432 

 

 

109,168 

 

 

310,962 

 

 

302,393 

Grain

 

 

113,567 

 

 

84,416 

 

 

252,490 

 

 

189,403 

Agronomy products

 

 

10,294 

 

 

9,027 

 

 

42,612 

 

 

40,174 

Other

 

 

24,688 

 

 

6,838 

 

 

55,682 

 

 

17,918 

 

 

$

947,413 

 

$

957,018 

 

$

2,593,163 

 

$

2,630,921 

 

 

 

 

The following are total assets for our operating segments for the periods indicated (in thousands):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

September 30,

 

December 31,

 

 

2012

 

2011

Total assets:

 

 

 

 

 

 

Ethanol production

 

$

842,505 

 

$

879,500 

Corn oil production

 

 

24,014 

 

 

24,601 

Agribusiness

 

 

236,010 

 

 

233,201 

Marketing and distribution

 

 

199,589 

 

 

181,466 

Corporate assets

 

 

142,467 

 

 

121,429 

Intersegment eliminations

 

 

(28,051)

 

 

(19,369)

 

 

$

1,416,534 

 

$

1,420,828 

 

 

 

 

 

 

 

12

 


 

 

4.  INVENTORIES

 

Inventories are carried at the lower of cost or market, except grain held for sale, which is valued at market value. During the nine months ended September 30, 2012, the Company recorded a $2.7 million lower of cost or market adjustment in cost of goods sold within the ethanol production segment. The components of inventories are as follows (in thousands):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

September 30,

 

December 31,

 

2012

 

2011

Finished goods

$

51,622 

 

$

57,882 

Grain held for sale

 

123,376 

 

 

112,948 

Raw materials

 

28,623 

 

 

23,215 

Petroleum & agronomy products held for sale

 

16,252 

 

 

14,206 

Work-in-process

 

11,359 

 

 

11,418 

Supplies and parts

 

9,998 

 

 

9,401 

 

$

241,230 

 

$

229,070 

 

5.  GOODWILL

 

The Company did not have any changes in the total carrying amount of goodwill during the nine months ended September 30, 2012, which was $40.9 million. Goodwill of $30.3 million is attributable to the ethanol production segment and $10.6 million is attributable to the marketing and distribution segment.

 

The Company reviews goodwill for impairment at least annually, as of October 1, or more frequently whenever events or changes in circumstances indicate that impairment may have occurred. In 2012, ethanol production has experienced a compressed commodity margin environment which adversely affected the business climate in which the Company operates. Also, during 2012, the Company experienced a decline in market capitalization as its stock price reached a 52-week low in the third quarter. As a result of these two adverse factors, the Company performed an interim review of goodwill for potential impairment for its ethanol production reporting units as of September 30, 2012. The Company performs a two-step impairment test to evaluate goodwill. Under the first step, the estimated fair value of the reporting unit is compared with its carrying value (including goodwill). If the estimated fair value of the reporting unit is less than its carrying value, the Company completes a second step to determine the amount of the goodwill impairment that should be recorded. The Company determined the fair value of the applicable ethanol production reporting units using a combination of the income approach (discounted cash flows of future benefit streams) and market approach (market prices from recent comparable sales transactions). Judgments and assumptions related to revenue, operating income, future short-term and long-term growth rates, weighted average cost of capital, interest, capital expenditures, cash flows, and market conditions are inherent in developing the discounted cash flow model. As a result of the interim review, the Company determined that the estimated fair value of its ethanol production reporting units substantially exceeded each of their respective carrying values and no goodwill impairment charge was deemed to be required. The Company will update its goodwill impairment analysis during the fourth quarter of 2012 in connection with its annual impairment testing.

 

 

6.  DERIVATIVE FINANCIAL INSTRUMENTS

 

At September 30, 2012, the Company’s consolidated balance sheet reflects a  deferred gain, net of tax, of $19.6 million in accumulated other comprehensive income. The Company expects all of the deferred gains at September 30, 2012 will be reclassified into income over the next 12 months as a result of hedged transactions that are forecasted to occur. The amount ultimately realized in income, however, will differ as commodity prices change.

 

Fair Values of Derivative Instruments

 

The following table provides information about the fair values of our derivative financial instruments and the line items in the consolidated balance sheets in which the fair values are reflected:

13

 


 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Asset Derivatives'

 

Liability Derivatives'

 

Fair Value

 

Fair Value

 

September 30,

 

December 31,

 

September 30,

 

December 31,

 

2012

 

2011

 

2012

 

2011

Derivative financial instruments (1)

$

25,834 
(2)

$

19,022 
(3)

$

 -

 

$

 -

Other assets

 

172 

 

 

 

 

 

 

 

 

 

Accrued and other liabilities

 

 -

 

 

 -

 

 

15,007 

 

 

5,280 

Other liabilities

 

 -

 

 

 -

 

 

189 

 

 

137 

Total

$

26,006 

 

$

19,022 

 

$

15,196 

 

$

5,417 

 

(1)             Derivative financial instruments as reflected on the balance sheet include a margin deposit asset of $16.9 million and a margin deposit liability of $1.6 million at September 30, 2012 and December 31, 2011, respectively.

(2)             Balance at September 30, 2012, includes $8.6 million of net unrealized gains on derivative financial instruments designated as cash flow hedging instruments.

(3)    Balance at December 31, 2011, includes $12.2 million of net unrealized gains on derivative financial instruments designated as cash flow hedging instruments.

 

 

Refer to Note 2 - Fair Value Disclosures, which also contains fair value information related to derivative financial instruments.

 

Effect of Derivative Instruments on Consolidated Statements of Operations and Consolidated Statements of Stockholders’ Equity and Comprehensive Income

 

The following tables provide information about the gain or loss recognized in income and other comprehensive income on our derivative financial instruments and the line items in the financial statements in which such gains and losses are reflected:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Gains (Losses) on Derivative Instruments Not

 

Three Months Ended
September 30,

 

Nine Months Ended
September 30,

Designated in a Hedging Relationship

 

2012

 

2011

 

2012

 

2011

Revenue

 

$

(10,190)

 

$

1,535 

 

$

(11,469)

 

$

617 

Cost of goods sold

 

 

(6,255)

 

 

(9,718)

 

 

(10,580)

 

 

(29,831)

Net decrease recognized in earnings before tax

 

$

(16,445)

 

$

(8,183)

 

$

(22,049)

 

$

(29,214)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Gain (Loss) Due to Ineffectiveness

 

Three Months Ended

September 30,

 

Nine Months Ended

September 30,

of Cash Flow Hedges

 

2012

 

2011

 

2012

 

2011

Revenue

 

$

(22)

 

$

340 

 

$

(10)

 

$

320 

Cost of goods sold

 

 

(405)

 

 

(576)

 

 

(29)

 

 

(1,231)

Net decrease recognized in earnings before tax

 

$

(427)

 

$

(236)

 

$

(39)

 

$

(911)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Gains (Losses) Reclassified from Accumulated

Other Comprehensive Income (Loss)

 

Three Months Ended September 30,

 

Nine Months Ended

September 30,

into Net Income (Loss)

 

2012

 

2011

 

2012

 

2011

Revenue

 

$

(1,994)

 

$

(9,608)

 

$

1,563 

 

$

(31,097)

Cost of goods sold

 

 

13,291 

 

 

(5,342)

 

 

7,939 

 

 

8,649 

Net increase (decrease) recognized in earnings before tax

 

$

11,297 

 

$

(14,950)

 

$

9,502 

 

$

(22,448)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Effective Portion of Cash Flow Hedges Recognized in

 

Three Months Ended

September 30,

 

Nine Months Ended

September 30,

Other Comprehensive Income (Loss)

 

2012

 

2011

 

2012

 

2011

Commodity Contracts

 

$

26,497 

 

$

(16,806)

 

$

45,538 

 

$

(33,031)

 

 

 

 

 

There were no gains or losses due to the discontinuance of cash flow hedge treatment or fair value hedge exposure during the three and nine months ended September 30, 2012. 

14

 


 

 

The following table summarizes the volumes of open commodity derivative positions as of September 30, 2012 (in thousands):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

September 30, 2012

 

 

Exchange Traded

 

Non-Exchange Traded

 

 

 

 

Derivative Instruments

 

Net Long & (Short) (1)

 

Long (2)

 

(Short) (2)

 

Unit of Measure

 

Commodity

Futures

 

(22,281)

 

 

 

 

 

Bushels

 

Corn, Soybeans and Wheat

Futures

 

25,830 

(3)

 

 

 

 

Bushels

 

Corn

Futures

 

(14,520)

 

 

 

 

 

Gallons

 

Ethanol

Futures

 

(123,858)

(3)

 

 

 

 

Gallons

 

Ethanol

Options

 

(377)

 

 

 

 

 

Bushels

 

Corn and Soybeans

Options

 

(1,100)

 

 

 

 

 

Gallons

 

Ethanol

Options

 

161 

 

 

 

 

 

mmBTU

 

Natural Gas

Forwards

 

 

 

23,212 

 

(5,406)

 

Bushels

 

Corn, Soybeans, Wheat and Milo

Forwards

 

 

 

34,788 

 

(141,362)

 

Gallons

 

Ethanol

Forwards

 

 

 

 

(101)

 

Tons

 

Distillers Grains

Forwards

 

 

 

144 

 

(30,384)

 

Pounds

 

Corn Oil

 

 

 

 

 

 

 

 

 

 

 

 

(1)

Exchange traded futures and options are presented on a net long and (short) position basis. Options are presented on a delta-adjusted basis.

(2)

Non-exchange traded forwards are presented on a gross long and (short) position basis including both fixed-price and basis contracts.

(3)

Futures used for cash flow hedges.

 

 

 

Energy trading contracts that do not involve physical delivery are presented net in revenues on the consolidated statements of operations. Revenues and cost of goods sold under such contracts are summarized in the table below for the periods indicated (in thousands):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

September 30,

 

Nine Months Ended

September 30,

 

2012

 

2011

 

2012

 

2011

Revenue

$

18,285 

 

$

83,909 

 

$

30,848 

 

$

107,721 

Cost of goods sold

 

17,521 

 

 

82,703 

 

 

30,013 

 

 

105,502 

 

 

 

 

15

 


 

 

7.  DEBT

 

The principal balances of the components of debt are as follows (in thousands):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

September 30,

2012

 

December 31,

2011

Green Plains Bluffton:

 

 

 

 

 

$70.0 million term loan

$

42,768 

 

$

48,018 

$20.0 million revolving term loan

 

20,000 

 

 

20,000 

$22.0 million revenue bond

 

17,510 

 

 

19,120 

Green Plains Central City:

 

 

 

 

 

$55.0 million term loan

 

39,973 

 

 

46,558 

$30.5 million revolving term loan

 

27,739 

 

 

24,739 

$11.0 million revolving line of credit

 

10,000 

 

 

 -

Equipment financing loan

 

122 

 

 

170 

Green Plains Holdings II:

 

 

 

 

 

$34.1 million term loan

 

 -

 

 

27,914 

$42.6 million revolving term loan

 

 -

 

 

35,679 

$15.0 million revolver

 

 -

 

 

15,000 

$26.4 million term loan

 

23,414 

 

 

 -

$51.1 million revolving term loan

 

48,000 

 

 

 -

Other

 

194 

 

 

194 

Green Plains Obion:

 

 

 

 

 

$60.0 million term loan

 

15,879 

 

 

25,670 

$37.4 million revolving term loan

 

37,400 

 

 

36,200 

Note payable

 

54 

 

 

85 

Equipment financing loan

 

329 

 

 

445 

Economic development grant

 

1,357 

 

 

1,424 

Green Plains Ord:

 

 

 

 

 

$25.0 million term loan

 

18,287 

 

 

21,300 

$13.0 million revolving term loan

 

12,151 

 

 

12,151 

$5.0 million revolving line of credit

 

4,349 

 

 

3,349 

Green Plains Otter Tail:

 

 

 

 

 

$30.3 million term loan

 

23,961 

 

 

27,386 

$4.7 million revolver

 

4,675 

 

 

4,675 

$19.2 million note payable

 

18,980 

 

 

18,883 

Capital lease payable

 

82 

 

 

166 

Green Plains Shenandoah:

 

 

 

 

 

$30.0 million term loan

 

400 

 

 

6,068 

$17.0 million revolving term loan

 

17,000 

 

 

17,000 

Green Plains Superior:

 

 

 

 

 

$23.5 million term loan

 

16,625 

 

 

20,750 

$10.0 million revolving term loan

 

10,000 

 

 

10,000 

Equipment financing loan

 

106 

 

 

156 

 

 

 

 

 

 

Continued on the following page

 

 

 

            

16

 


 

 

 

 

 

 

 

 

 

 

 

 

Continued from the previous page

 

 

 

 

 

 

 

September 30,
2012

 

December 31,
2011

Green Plains Grain:

 

 

 

 

 

$30.0 million term loan

 

28,333 

 

 

27,833 

$195.0 revolving loan

 

69,000 

 

 

27,000 

Inventory financing arrangements

 

16,237 

 

 

8,894 

Equipment financing loans

 

135 

 

 

311 

Notes payable

 

 -

 

 

2,000 

Green Plains Trade:

 

 

 

 

 

$70.0 million revolving loan

 

43,890 

 

 

33,705 

Corporate:

 

 

 

 

 

$90.0 million convertible notes

 

90,000 

 

 

90,000 

Notes Payable

 

28,787 

 

 

1,625 

Capital Lease

 

455 

 

 

606 

Other

 

805 

 

 

1,692 

Total debt

 

688,997 

 

 

636,766 

Less: short-term notes payable and other

 

(157,914)

 

 

(69,599)

Less: current portion of long-term debt

 

(73,092)

 

 

(73,760)

Long-term debt

$

457,991 

 

$

493,407 

 

 

 

 

 

 

Ethanol Production Segment

 

·

Term Loans

 

Scheduled principal payments are as follows: 

 

 

 

 

 

•  

Green Plains Bluffton

$0.6 million per month

•  

Green Plains Central City

$0.4 million per month

•  

Green Plains Holdings II

$1.5 million per quarter

•  

Green Plains Obion

$2.4 million per quarter

•  

Green Plains Ord

$0.2 million per month

•  

Green Plains Otter Tail

$0.4 million per month

•  

Green Plains Shenandoah

$1.2 million per quarter

•  

Green Plains Superior

$1.4 million per quarter

 

Final maturity dates (at the latest) are as follows:

 

 

 

 

 

•  

Green Plains Bluffton

November 19, 2013

•  

Green Plains Central City

July 1, 2016

•  

Green Plains Holdings II

July 1, 2016

•  

Green Plains Obion

August 20, 2014

•  

Green Plains Ord

July 1, 2016

•  

Green Plains Otter Tail

September 1, 2018

•  

Green Plains Shenandoah

May 20, 2013

•  

Green Plains Superior

July 20, 2015

·

Revolving Term LoansThe revolving term loans are generally available for advances throughout the life of the commitment, subject, in certain cases, to borrowing base restrictions. Allowable advances under the Green Plains Shenandoah loan agreement are reduced by $2.4 million each six-month period commencing on June 1, 2013. Allowable advances under the Green Plains Superior loan agreement are reduced by $2.5 million each six-month period commencing on the first day of the month beginning six months after repayment of the term loan, but in no event later than January 1, 2016. Allowable advances under the Green Plains Obion loan agreement are reduced by

17

 


 

 

$4.7 million on a semi-annual basis commencing on March 1, 2015. Allowable advances under the Green Plains Holdings II loan agreement are reduced by $2.7 million on a semi-annual basis commencing on April 1, 2012 and are reduced by $5.7 million on a semi-annual basis commencing on October 1, 2016. Interest-only payments are due each month on all revolving term loans until the final maturity date for the Green Plains Bluffton, Green Plains Central City, Green Plains Ord, Green Plains Otter Tail, Green Plains Shenandoah, and Green Plains Superior loan agreements.

 

Final maturity dates (at the latest) are as follows:

 

 

 

 

 

•  

Green Plains Bluffton

November 19, 2013

•  

Green Plains Central City

July 1, 2016

•  

Green Plains Holdings II

October 1, 2018

•  

Green Plains Obion

September 1, 2018

•  

Green Plains Ord

July 1, 2016

•  

Green Plains Otter Tail

March 19, 2013

•  

Green Plains Shenandoah

November 1, 2016

•  

Green Plains Superior

July 1, 2017

 

Green Plains Bluffton also received $22.0 million in Subordinate Solid Waste Disposal Facility Revenue Bond funds from the City of Bluffton, Indiana. The revenue bond requires: (1) semi-annual principal and interest payments of approximately $1.5 million through March 1, 2019, and (2) a final principal and interest payment of $3.745 million on September 1, 2019. At September 30, 2012, Green Plains Bluffton had $2.5 million of cash that was restricted as to use for payment towards the current maturity and interest of the revenue bond. Such cash is presented as restricted cash on the consolidated balance sheet.

 

Subsidiaries within the ethanol production segment were in compliance with their debt covenants as of September 30, 2012.

 

Agribusiness Segment

 

The Green Plains Grain loans are comprised of a $30.0 million amortizing term loan and a $195.0 million revolving credit facility with various lenders. The term loan and revolving credit facility mature on November 1, 2021 and October 28, 2013, respectively.

 

The $30.0 million amortizing term loan requires equal monthly payments of principal sufficient to amortize the loan in full over a 15-year period, plus interest, with the remaining outstanding balance and all accrued interest due on November 1, 2021, the loan maturity date. The loan bears interest at a fixed rate of 6.0% per annum. As security for the loan, the lender received a first priority lien on certain real estate and other property owned by the subsidiaries within the agribusiness segment.

 

The revolving credit facility includes total revolving credit commitments of $195.0 million and an accordion feature whereby amounts available under the facility may be increased by up to $55.0 million of new lender commitments upon agent approval. As security for the revolving credit facility, the lender received a first priority lien on certain cash, inventory, machinery, accounts receivable and other assets owned by subsidiaries of the agribusiness segment. Advances are subject to interest charges at a rate per annum equal to the LIBOR rate for the outstanding period plus the applicable margin or a rate per annum equal to the base rate plus the applicable margin.

 

Subsidiaries within the agribusiness segment were in compliance with their debt covenants at September 30, 2012.

 

Inventory Financing Arrangements

 

The Company has entered into short-term inventory financing agreements with a financial institution. At September 30, 2012, 1.9 million bushels of wheat had been designated as collateral under these agreements at initial values totaling $15.1 million. The Company has accounted for the agreements as short-term notes, rather than sales, and has elected the fair value option to offset fluctuations in market prices of the inventory. At September 30, 2012, the grain inventory and short-term notes payable were valued at $16.2 million and were measured using Level 2 inputs.

 

18

 


 

 

Marketing and Distribution Segment

 

The Green Plains Trade loan is comprised of a senior secured revolving credit facility. Under the loan agreement, as amended, the lender will loan up to $70.0 million, subject to a borrowing base equal to 85% of eligible receivables. The balance is subject to interest charges of either: (1) base rate (lender’s commercial floating rate plus 2.5%); or, (2) LIBOR plus 3.5%. At September 30, 2012, Green Plains Trade had $19.3 million in cash that was restricted as to use for payment towards the loan agreement. Such cash is presented in restricted cash on the consolidated balance sheets. The amended revolving credit facility expires on March 31, 2014.

 

Green Plains Trade was in compliance with its debt covenants at September 30, 2012.

 

Corporate Activities

 

            In November 2010, the Company issued $90.0 million of 5.75% Convertible Senior Notes due 2015. The Notes represent senior, unsecured obligations of the Company, with interest payable on May 1 and November 1 of each year. The Notes may be converted into shares of the Company’s common stock and cash in lieu of fractional shares of the common stock based on a conversion rate initially equal to 69.7788 shares of the common stock per $1,000 principal amount of Notes, which is equal to an initial conversion price of $14.33 per share. The conversion rate is subject to adjustment upon the occurrence of specified events. The Company may redeem for cash all, but not less than all, of the Notes at any time on and after November 1, 2013, if the last reported sale price of the Company’s common stock equals or exceeds 140% of the applicable conversion price for a specified time period, at a redemption price equal to 100% of the principal amount of the Notes, plus accrued and unpaid interest.

 

In conjunction with the March 9, 2012 repurchase of its common stock from a subsidiary of NTR plc, which was previously the Company’s largest shareholder, the Company signed a one-year promissory note bearing 5% interest per annum in the amount of $27.2 million. The $27.2 million note is secured by the shares repurchased and the Company’s interest in Green Plains Shenandoah LLC.

 

Capitalized Interest

 

The Company had $169 thousand and $285 thousand in capitalized interest during the three and nine months ended September 30, 2012, respectively.

 

Restricted Net Assets

 

            At September 30, 2012, there were approximately $475.4 million of net assets at the Company’s subsidiaries that were not available to be transferred to the parent company in the form of dividends, loans or advances due to restrictions contained in the credit facilities of these subsidiaries.

 

8.  STOCK-BASED COMPENSATION

 

The Company has equity incentive plans which reserve a combined total of 3.5 million shares of common stock for issuance pursuant to their terms. The plans provide for the granting of shares of stock, including options to purchase shares of common stock, stock appreciation rights tied to the value of common stock, non-vested stock and non-vested stock unit awards to eligible employees, non-employee directors and consultants. The Company measures share-based compensation grants at fair value on the grant date, adjusted for estimated forfeitures. The Company records noncash compensation expense related to equity awards in its financial statements over the requisite service period on a straight-line basis. All of the Company’s existing share-based compensation awards have been determined to be equity awards.

 

            For stock options granted during the first nine months of 2012, the fair value of options granted was estimated on the date of grant using the Black-Scholes option-pricing model, a pricing model acceptable under GAAP, with the following weighted-average assumptions:

19

 


 

 

 

 

Expected life

6.0 

Interest rate

0.63% 

Volatility

76.26% 

Dividend yield

 -

            The expected life of options granted represents the period of time in years that options granted are expected to be outstanding. The interest rate represents the annual interest rate a risk-free investment could potentially earn during the expected life of the option grant. Expected volatility is based on weighted-average historical volatility of the Company’s common stock.

 

A summary of stock option activity for the nine months ended September 30, 2012 is as follows:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Shares

 

Weighted-Average Exercise Price

 

Weighted-Average Remaining Contractual Term (in years)

 

Aggregate Intrinsic Value (in thousands)

 

 

 

 

 

 

 

 

 

 

Outstanding at December 31, 2011

1,122,499 

 

$

15.68 

 

3.8

 

$

1,374 

Granted

10,000 

 

 

4.32 

 

 

 

 

 

Exercised

(16,332)

 

 

8.71 

 

 

 

 

45 

Forfeited

 -

 

 

 -

 

 

 

 

 

Expired

(325,000)

 

 

30.00 

 

 

 

 

 

Outstanding at September 30, 2012

791,167 

 

$

9.79 

 

4.3

 

$

147 

Exercisable at September 30, 2012 (1)

733,167 

 

$

9.68 

 

4.1

 

$

135 
(1)

Includes in-the-money options totaling 52,500 shares at a weighted-average exercise price of $3.28.

 

The Company’s option awards allow employees to exercise options through cash payment to the Company for the shares of common stock or through a simultaneous broker-assisted cashless exercise of a share option, through which the employee authorizes the exercise of an option and the immediate sale of the option shares in the open market. The Company uses newly-issued shares of common stock to satisfy its share-based payment obligations. 

 

The following table summarizes non-vested stock award and deferred stock unit activity for the nine months ended September 30, 2012:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Non-Vested Shares and Deferred Stock Units

 

Weighted-Average Grant-Date Fair Value

 

Weighted-Average Remaining Vesting Term (in years)

 

 

 

 

 

 

 

Nonvested at December 31, 2011

486,012 

 

$

11.81 

 

 

Granted

550,011 

 

 

10.57 

 

 

Forfeited

(9,766)

 

 

12.07 

 

 

Vested

(370,082)

 

 

10.59 

 

 

Nonvested at September 30, 2012

656,175 

 

$

11.46 

 

1.9

 

            Compensation costs expensed for share-based payment plans described above during the three and nine months ended September 30, 2012 were approximately $1.0 million and $4.3 million, respectively, and during the three and nine months ended September 30, 2011 were approximately $0.9 million and $3.5 million, respectively. At September 30, 2012, there were $5.4 million of unrecognized compensation costs from share-based compensation arrangements, which are related to non-vested awards. This compensation is expected to be recognized over a weighted-average period of approximately 1.8 years. The potential tax benefit realizable for the anticipated tax deductions of the exercise of share-based payment arrangements generally would approximate 38% of these expense amounts.

 

 

20

 


 

 

9.  EARNINGS PER SHARE

 

Basic earnings per common shares, or EPS, is calculated by dividing net income available to common stockholders by the weighted average number of common shares outstanding during the period. Diluted EPS is computed by dividing net income on an as-if-converted basis available to common stockholders by the weighted average number of common shares outstanding during the period, adjusted for the dilutive effect of any outstanding dilutive securities. Adjusting net income to net income on an as-if-converted basis and adjusting the weighted average number of common shares outstanding for the effect of any outstanding dilutive securities is antidilutive when a net loss has been realized. The reconciliations of net income to net income on an as-if-converted basis and basic and diluted earnings per share are as follows (in thousands):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

 

Nine Months Ended

 

September 30,

 

September 30,

 

2012

 

2011

 

2012

 

2011

Net income (loss) attributable to Green Plains

$

(1,002)

 

$

12,429 

 

$

(21,244)

 

$

25,152 

Weighted average shares outstanding - basic

 

29,655 

 

 

35,624 

 

 

30,499 

 

 

36,075 

Income (loss) attributable to Green Plains stockholders - basic

$

(0.03)

 

$

0.35 

 

$

(0.70)

 

$

0.70 

Net income (loss) attributable to Green Plains

$

(1,002)

 

$

12,429 

 

$

(21,244)

 

$

25,152 

Interest and amortization on convertible debt, net of tax effect

 

 -

 

 

925 

 

 

 -

 

 

2,770 

Net income (loss) attributable to Green Plains on an as-if-converted basis

$

(1,002)

 

$

13,354 

 

$

(21,244)

 

$

27,922 

Weighted average shares outstanding - basic

 

29,655 

 

 

35,624 

 

 

30,499 

 

 

36,075 

Effect of dilutive convertible debt

 

 -

 

 

6,280 

 

 

 -

 

 

6,280 

Effect of dilutive stock-based compensation awards

 

 -

 

 

247 

 

 

 -

 

 

256 

Total potential shares outstanding

 

29,655 

 

 

42,151 

 

 

30,499 

 

 

42,611 

Income (loss) attributable to Green Plains stockholders - diluted

$

(0.03)

 

$

0.32 

 

$

(0.70)

 

$

0.66 

 

 

 

 

            Excluded from the computations of diluted EPS for the three and nine months ended September 30, 2012 were stock-based compensation awards totaling 1.3 million and 1.1 million shares, respectively and for the three and nine months ended September 30, 2011 were stock-based compensation awards totaling 0.7 million and 0.9 million shares, respectively, because the exercise prices or the grant-date fair value, as applicable, of the corresponding awards were greater than the average market price of the Company’s common stock during the respective periods. For the three and nine months ended September 30, 2012, 6.3 million and 6.4 million shares, respectively, related to stock-based compensation awards and convertible debt were also excluded from the computation of diluted EPS as the inclusion of these shares would have been antidilutive. As consideration for the acquisition of the Lakota and Riga ethanol plants in October 2010, the Company issued warrants for 700,000 shares of its stock at a price of $14.00 per share exercisable for a period of three years from the closing date. The warrants are excluded from the computations of diluted EPS as the exercise price is greater than the average market price of the Company’s common stock for the three and nine months ended September 30, 2012 and 2011.

 

 

21

 


 

 

10.  STOCKHOLDERS’ EQUITY

 

Components of stockholders’ equity are as follows (in thousands):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Accum.

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other

 

Total

 

 

 

 

 

 

Additional

 

 

Comp

 

Green Plains

Non-

Total

 

Common Stock

Paid-in

Retained

Income

Treasury Stock

Stockholders'

Controlling

Stockholders'

 

Shares

Amount

Capital

Earnings

(Loss)

Shares

Amount

Equity

Interest

Equity

Balance, December 31, 2011

36,414 

$

36 

$

440,469 

$

95,761 

$

(2,953)
3,500 

$

(28,201)

$

505,112 

$

245 

$

505,357 

Net loss

 -

 

 -

 

 -

 

(21,244)

 

 -

 -

 

 -

 

(21,244)

 

(13)

 

(21,257)

Other comprehensive income,

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

net of tax

 -

 

 -

 

 -

 

 -

 

22,548 

 -

 

 -

 

22,548 

 

 -

 

22,548 

Repurchase of common stock

 -

 

 -

 

 -

 

 -

 

 -

3,700 

 

(37,607)

 

(37,607)

 

 -

 

(37,607)

Stock-based compensation

425 

 

 

3,148 

 

 -

 

 -

 -

 

 -

 

3,149 

 

 -

 

3,149 

Stock options exercised

16 

 

 -

 

142 

 

 -

 

 -

 -

 

 -

 

142 

 

 -

 

142 

Other

 -

 

 -

 

(13)

 

 -

 

 -

 -

 

 -

 

(13)

 

 -

 

(13)

Balance, September 30, 2012

36,855 

$

37 

$

443,746 

$

74,517 

$

19,595 
7,200 

$

(65,808)

$

472,087 

$

232 

$

472,319 

 

 

 

 

            On March 9, 2012, the Company repurchased 3.7 million shares of its common stock for $37.2 million. Shares of repurchased common stock are recorded at cost as treasury stock and result in a reduction of stockholders’ equity in the accompanying consolidated balance sheets. When shares are reissued, the Company will use the weighted average cost method for determining the cost basis. The difference between the cost of the shares and the issuance price will be added or deducted from additional paid-in capital. The Company does not have a share repurchase program and does not intend to retire the repurchased shares.

 

11.  INCOME TAXES

 

The Company records income tax expense or benefit during interim periods based on its best estimate of the annual effective tax rate. Certain items are given discrete period treatment and, as a result, the tax effects of such items are reported in full in the relevant interim period.

 

The income tax benefit for the three and nine months ended September 30, 2012 was $0.6 million and $12.7 million, respectively, compared to an expense of $7.0 million and $14.2 million, respectively, for the same periods in 2011.The effective tax rate (calculated as the ratio of income tax expense to income before income taxes) was approximately 37.5% and 36.3% for the first nine months of 2012 and 2011, respectively. The effective tax rate for the nine months ended September 30, 2011, reflects the release of a portion of valuation allowances provided against certain of the Company’s deferred tax assets, primarily federal and state net operating losses and tax credits due to anticipated income in future periods.

 

The Company’s unrecognized tax benefits at September 30, 2012 and December 31, 2011 were immaterial. There was no change in the Company’s liabilities related to unrecognized tax benefits during the first nine months of 2012.

 

            The 2012 annual effective tax rate can be affected as a result of variances among the estimates and amounts of full-year sources of taxable income (among the various states), the realization of tax credits, adjustments that may arise from the resolution of tax matters under review, variances in the release of valuation allowances and the Company’s assessment of its liability for uncertain tax positions.

 

12.  COMMITMENTS AND CONTINGENCIES

 

Operating Leases

 

The Company leases certain facilities and parcels of land under agreements that expire at various dates. For accounting purposes, rent expense is based on a straight-line amortization of the total payments required over the lease term. The Company incurred lease expenses of $4.8 million and $13.9 million during the three and nine months ended September 30, 2012, respectively, and $4.2 million and $11.8 million during the three and nine months ended September 30, 2011, respectively. Aggregate minimum lease payments under these agreements for the remainder of 2012 and in future fiscal years are as follows (in thousands):

 

 

 

 

 

 

 

 

 

Year Ending December 31,

 

Amount

2012

 

$

5,264 

2013

 

 

18,701 

2014

 

 

12,284 

2015

 

 

10,127 

2016

 

 

7,918 

Thereafter

 

 

6,057 

Total

 

$

60,351 

22

 


 

 

 

 

 

Commodities

 

As of September 30, 2012 the Company had contracted for future purchases of grain, natural gas, ethanol and distillers grains valued at approximately $457.5 million, $1.8 million, $30.5 million and $0.8 million, respectively

 

Legal

 

In April 2011, Aventine Renewable Energy, Inc. filed a complaint in the United States Bankruptcy Court for the District of Delaware in connection with its Chapter 11 bankruptcy naming as defendants Green Plains Renewable Energy, Inc., Green Plains Obion LLC, Green Plains Bluffton LLC, Green Plains VBV LLC and Green Plains Trade Group LLC. This action alleged $24.4 million of damages from preferential transfers or, in the alternative, $28.4 million of damages from fraudulent transfers under an ethanol marketing agreement and an unspecified amount of damages for a continuing breach of a termination agreement related to rail cars. In April 2012, the parties mutually agreed to a negotiated settlement whereby the Company agreed to a cash payment and the purchase of 20 million gallons of ethanol from Aventine over a four-month period beginning in May 2012. An after-tax charge of $2.4 million for the settlement was reflected in operations for the nine months ended September 30, 2012.

 

In addition to the above-described proceeding, the Company is currently involved in other litigation that has arisen in the ordinary course of business, but it does not believe that any other pending litigation will have a material adverse effect on its financial position, results of operations or cash flows.

 

13.  RELATED PARTY TRANSACTIONS

 

Short-Term Note Payable

 

On March 9, 2012, the Company repurchased 3.7 million shares of its common stock from a subsidiary of NTR plc, which was previously the largest shareholder of the Company, for $37.2 million. The Company paid $10.0 million in cash and issued a secured note bearing 5% interest per annum for $27.2 million that is due on March 9, 2013. The $27.2 million note is secured by the shares repurchased and the Company’s interest in Green Plains Shenandoah LLC. At September 30, 2012, $27.2 million was outstanding on the note payable.

 

Commercial Contracts

 

Three subsidiaries of the Company have executed separate financing agreements for equipment with AXIS Capital Inc. Gordon F. Glade, President and Chief Executive Officer of AXIS Capital, is a member of our Board of Directors. Totals of $0.2 million and $0.5 million were included in debt at September 30, 2012 and December 31, 2011, respectively, under these financing arrangements. Payments, including principal and interest, totaled $37 thousand and $0.2 million during the three and nine months ended September 30, 2012, respectively, and $0.2 million and $0.5 million during the three and nine months ended September 30, 2011, respectively. The highest amount outstanding during the nine months ended September 30, 2012 was $0.4 million, and the weighted average interest rate for all financing agreements with AXIS Capital was 6.1%.

 

The Company has entered into ethanol purchase, sale and throughput agreements with Center Oil Company. Gary R. Parker, President and Chief Executive Officer of Center Oil, is a member of our Board of Directors. During the three and nine months ended September 30, 2012, cash receipts from Center Oil totaled $12.0 million and $15.7 million, respectively, and cash payments to Center Oil totaled $3.4 million and $4.5 million for the same periods, respectively, on these contracts. During the three and nine months ended September 30, 2011, cash receipts from Center Oil totaled $24.1 million and $89.4 million, respectively, and cash payments to Center Oil totaled $3.1 million and $5.2 million for the same periods, respectively, on these contracts.  In October 2011, the Company also entered into an operating lease agreement with Center Oil in which the Company will pay $42 thousand per month for the lease of 35 railcars. The agreement is effective through September 30, 2013. The Company had $1.2 million and $1.0 million included in outstanding receivables from Center Oil at

23

 


 

 

September 30, 2012 and December 31, 2011, respectively. The Company had $0.5 million and $69 thousand in outstanding payables at September 30, 2012 and December 31, 2011, respectively under these purchase and sale agreements.

 

Aircraft Lease

 

            The Company has entered into an agreement with Hoovestol Inc. for the lease of an aircraft. Wayne B. Hoovestol, President of Hoovestol Inc., is Chairman of our Board of Directors. The Company has agreed to pay $6,667 per month for use of up to 100 hours per year of the aircraft. Any flight time in excess of 100 hours per year will incur additional hourly-based charges. During the three and nine months ended September 30, 2012, payments related to this agreement totaled $25 thousand and $90 thousand, respectively, and for the same periods in 2011 payments related to this agreement totaled $33 thousand and $105 thousand, respectively. The Company did not have any receivables from or payables to Hoovestol Inc. at September 30, 2012 and December 31, 2011.

 

14SUBSEQUENT EVENTS 

 

On October 26, 2012, the Company, along with two of its wholly-owned subsidiaries, entered into an Asset Purchase Agreement (the “Agreement”) to sell 12 grain elevators located in northwestern Iowa and western Tennessee. The transaction involves approximately 32.6 million bushels, or 83%, of the Company’s reported agribusiness grain storage capacity and all of its agronomy and retail petroleum operations. The estimated sales price for the facilities and certain related working capital is $133.1 million, including the assumption at closing of term debt of approximately $28.3 million. In addition, the Company expects to realize net proceeds from the liquidation of retained working capital of $86.7 million before the repayment of approximately $85.2 million under a revolving credit facility and inventory financing arrangements. Working capital and amounts outstanding under the term debt are based on September 30, 2012 balances and will be adjusted to final amounts at closing. Net cash proceeds, including working capital liquidation, are expected to be approximately $103.8 million, and the Company expects to report a pre-tax gain from this sale of approximately $46.0 million. The following table sets forth the carrying amounts of the major classes of assets and liabilities included as part of the disposal group as of September 30, 2012 (in thousands):

 

 

 

 

 

As of September 30, 2012

 

 

 

Current assets

$

193,179 

Property and equipment, net

 

45,191 

Current liabilities

 

156,198 

Long-term debt, net

 

26,437 

 

The closing of the transaction, which is expected to occur during the fourth quarter of 2012, is subject to customary closing conditions and regulatory approvals. The Agreement contains normal and customary representations and warranties, indemnification obligations and break-up fees. The Agreement also contains an undertaking by the Company for a period of three years following closing not to compete with the businesses being sold in a 75-mile radius of the facilities, subject to certain exceptions.

 

 

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Item 2.  Management’s Discussion and Analysis of Financial Condition and Results of Operations.

 

General

 

The following discussion and analysis provides information which management believes is relevant to an assessment and understanding of our consolidated financial condition and results of operations. This discussion should be read in conjunction with the consolidated financial statements included herewith and notes to the consolidated financial statements thereto and our annual report on Form 10-K for the year ended December 31, 2011 including the consolidated financial statements, accompanying notes and the risk factors contained therein.

 

Cautionary Information Regarding Forward-Looking Statements

 

This report contains forward-looking statements based on current expectations that involve a number of risks and uncertainties. Forward-looking statements generally do not relate strictly to historical or current facts, but rather to plans and objectives for future operations based upon management’s reasonable estimates of future results or trends, and include statements preceded by, followed by, or that include words such as “anticipates,” “believes,” “continue,” “estimates,” “expects,” “intends,” “outlook,” “plans,” “predicts,” “may,” “could,” “should,” “will,” and words and phrases of similar impact, and include, but are not limited to, statements regarding future operating or financial performance, business strategy, business environment, key trends, and benefits of actual or planned acquisitions. In addition, any statements that refer to expectations, projections or other characterizations of future events or circumstances, including any underlying assumptions, are forward-looking statements. The forward-looking statements are made pursuant to safe harbor provisions of the Private Securities Litigation Reform Act of 1995. Although we believe that our expectations regarding future events are based on reasonable assumptions, any or all forward-looking statements in this report may turn out to be incorrect. They may be based on inaccurate assumptions or may not account for known or unknown risks and uncertainties. Consequently, no forward-looking statement is guaranteed, and actual future results may vary materially from the results expressed or implied in our forward-looking statements. The cautionary statements in this report expressly qualify all of our forward-looking statements. In addition, we are not obligated, and do not intend, to update any of our forward-looking statements at any time unless an update is required by applicable securities laws. Factors that could cause actual results to differ from those expressed or implied in the forward-looking statements include, but are not limited to, those discussed in Part I, Item 1A – Risk Factors of our annual report on Form 10-K for the year ended December 31, 2011 and in Item 1A of Part II of this Quarterly Report for the quarter ended September 30, 2012. Specifically, we may experience significant fluctuations in future operating results due to a number of economic conditions, including, but not limited to, completion of the sale of 12 grain elevators and related agronomy and retail petroleum operations, competition in the ethanol and other industries in which we compete, commodity market risks, financial market risks, counter-party risks, risks associated with changes to federal policy or regulation, expected corn oil recovery rates and operating expenses, risks related to closing and achieving anticipated results from acquisitions, and other risk factors detailed in our reports filed with the SEC. Actual results may differ from projected results due, but not limited, to unforeseen developments.

 

In light of these assumptions, risks and uncertainties, the results and events discussed in the forward-looking statements contained in this report or in any document incorporated by reference might not occur. Investors are cautioned not to place undue reliance on the forward-looking statements, which speak only as of the date of this report or the date of the document incorporated by reference in this report. We are not under any obligation, and we expressly disclaim any obligation, to update or alter any forward-looking statements, whether as a result of new information, future events or otherwise.

 

Overview

 

We are a leading, vertically-integrated producer, marketer and distributer of ethanol. We focus on generating stable operating margins through our diversified business segments and our risk management strategy. We believe that owning and operating assets throughout the ethanol value chain enables us to mitigate changes in commodity prices and differentiates us from companies focused only on ethanol production. Today, we have operations throughout the ethanol value chain, beginning upstream with our agronomy and grain handling operations, continuing through our ethanol, distillers grains and corn oil production operations and ending downstream with our ethanol marketing, distribution and blending facilities.

 

Management reviews our operations in the following four separate operating segments:

 

·

            Ethanol Production.  We are North America’s fourth largest ethanol producer. We operate a total of nine ethanol plants in Indiana, Iowa, Michigan, Minnesota, Nebraska and Tennessee, with approximately 740 million gallons per year, or mmgy, of total ethanol production capacity. At capacity, these plants collectively will consume approximately 265 million bushels of corn and produce approximately 2.1 million tons of distillers grains annually.  

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·

Corn Oil Production.  We operate corn oil extraction systems at all nine of our ethanol plants, with the capacity to produce approximately 145 million pounds annually. The corn oil systems are designed to extract non-edible corn oil from the whole stillage process immediately prior to production of distillers grains. Industrial uses for corn oil include feedstock for biodiesel, livestock feed additives, rubber substitutes, rust preventatives, inks, textiles, soaps and insecticides.

·

Agribusiness.  We operate three lines of business within our agribusiness segment: bulk grain, agronomy and petroleum. In our bulk grain business, we have 15 grain elevators with approximately 39.1 million bushels of total storage capacity. We sell fertilizer and other agricultural inputs and provide application services to area producers, through our agronomy business. Additionally, we sell petroleum products including diesel, soydiesel, blended gasoline and propane, primarily to agricultural producers and consumers. We believe our bulk grain business provides synergies with our ethanol production segment as it supplies a portion of the feedstock for our ethanol plants.

·

Marketing and Distribution.  Our in-house marketing business is responsible for the sales, marketing and distribution of all ethanol, distillers grains and corn oil produced at our nine ethanol plants. We also market and provide logistical services for ethanol and other commodities for third-party producers. Additionally, our wholly-owned subsidiary, BlendStar LLC, operates nine blending or terminaling facilities with approximately 625 mmgy of total throughput capacity in seven states in the south central United States. Construction of a BlendStar unit train terminal in Birmingham, Alabama, with additional throughput capacity of 300 mmgy, is expected to be completed and operational in the fourth quarter of 2012.

 

We intend to continue to take a disciplined approach in evaluating new opportunities related to potential acquisition of additional ethanol plants by considering whether the plants fit within the design, engineering and geographic criteria we have developed. In our marketing and distribution segment, our strategy is to renew existing marketing contracts, as well as enter new contracts with other ethanol producers. We also intend to pursue opportunities to develop or acquire additional grain elevators, specifically those located near our ethanol plants, subject to contractual restrictions following the proposed sale of certain of our agribusiness assets. We believe that owning additional agribusiness operations in close proximity to our ethanol plants enables us to strengthen relationships with local corn producers, allowing us to source corn more effectively and at a lower average cost. We also plan to continue to grow our downstream access to customers and are actively seeking new marketing opportunities with other ethanol producers. We also own 49% interest in BioProcess Algae LLC, which was formed to commercialize advanced photo-bioreactor technologies for growing and harvesting algal biomass. We continue our support of the BioProcess Algae joint venture.

 

To optimize the value of our assets, we began utilizing a portion of our railcar fleet to transport crude oil for third parties and to lease railcars to other users. At the end of the third quarter of 2012, we had 556 railcars leased to other users.

 

Recent Developments

 

On October 26, 2012, we entered into an asset purchase agreement to sell 12 grain elevators located in northwestern Iowa and western Tennessee. The transaction involves approximately 32.6 million bushels, or 83%, of our reported agribusiness grain storage capacity and all of our agronomy and retail petroleum operations. The estimated sales price for the facilities and certain related working capital is $133.1 million, including the assumption at closing of term debt of approximately $28.3 million. In addition, we expect to realize net proceeds from the liquidation of retained working capital of approximately $86.7 million before the repayment of approximately $85.2 million under a revolving credit facility and inventory financing arrangements. Working capital and amounts outstanding under debt and inventory financing arrangements are based on September 30, 2012 balances and will be adjusted to final amounts at closing. Net cash proceeds, including working capital liquidation, are expected to be approximately $103.8 million. We expect to report a pre-tax gain from this sale of approximately $46.0 million.

 

Industry Factors Affecting our Results of Operations

 

Variability of Commodity Prices.  Our operations and our industry are highly dependent on commodity prices, especially prices for corn, ethanol, distillers grains and natural gas. Because the market prices of these commodities are not always correlated, at times ethanol production may be unprofitable. As commodity price volatility poses a significant threat to our margin structure, we have developed a risk management strategy focused on locking in favorable operating margins when available. We continually monitor market prices of corn, natural gas and other input costs relative to the prices for ethanol and distillers grains at each of our production facilities. We create offsetting positions by using a combination of derivative instruments, fixed-price purchases and sales contracts, or a combination of strategies within strict limits. Our primary focus is

26

 


 

 

not to manage general price movements of individual commodities, for example to minimize the cost of corn consumed, but rather to lock in favorable profit margins whenever possible. By using a variety of risk management tools and hedging strategies, including our internally-developed real-time margin management system, we believe we are able to maintain a disciplined approach to price risks.

 

A combination of factors resulted in compressed ethanol margins in 2012. The ethanol industry increased production in the fourth quarter of 2011 to meet demand from ethanol blenders in order to take advantage of the volumetric ethanol excise tax credit prior to its expiration on December 31, 2011. As a result, ethanol stocks at the end of 2011 exceeded normal market levels which have caused ethanol margins to compress to near break-even levels in the first half of 2012. Additionally, corn prices traded to all-time highs during the third quarter of 2012 due to drought conditions in the midwestern region of the U.S.  According to the Energy Information Administration, or EIA, as an industry, ethanol producers have responded to the compressed margin environment by reducing production rates by approximately 18% by the end of the third quarter of 2012 compared to the fourth quarter of 2011. EIA data show ethanol imports increased from 51.5 million gallons in the first nine months of 2011 to 238.7 million gallons in the first nine months of 2012. According to the Renewable Fuels Association, Brazil was the top source of ethanol imports, accounting for approximately 91% of August 2012 shipments received in U.S. ports. Under the Renewable Fuels Standard II, or RFS II, certain parties are obligated to blend, in the aggregate, 2.0 billion gallons of advanced biofuels in 2012. During 2012, sugarcane ethanol imported from Brazil has been one of the most economical means for obligated parties to meet this standard. We believe the Brazilian government may increase the required percentage of ethanol in vehicle fuel sold in Brazil to 25 percent (from 20 percent) as sugarcane production rises, which would likely limit ethanol exports from Brazil into the U.S.

 

Further, during the third quarter of 2012, corn prices traded to all-time highs due to drought conditions in the midwestern region of the U.S. Estimates of supply and demand provided by the U.S. Department of Agriculture forecasted lower production levels and corresponding reduced demand levels as a result of higher corn prices. Consumers of corn, including ethanol producers, are competing for potentially reduced domestic supplies. These factors, in combination with reduced demand for motor fuels in the U.S. resulting from higher gasoline prices and more fuel-efficient vehicles, have adversely affected the margin environment in the first nine months of 2012. Also, during 2012, the Company experienced a decline in market capitalization as its stock price reached a 52-week low in the third quarter. As a result of these two adverse factors, we performed an interim review of goodwill for potential impairment as of September 30, 2012 for our ethanol production reporting units. As a result of this interim review, we determined that the estimated fair value of each of these reporting units substantially exceeded each of their respective carrying values and no goodwill impairment charge was deemed to be required. The margin environment in the fourth quarter of 2012, although improving, will likely be affected by these factors as well. We believe that U.S. ethanol production levels will continue to adjust to ethanol and corn supply and demand factors. Extended periods of depressed ethanol margins or market capitalization could lead to potential impairment of certain assets, including goodwill, in the future, which would adversely affect our operating results and certain leverage ratios for lending purposes.

 

There may be periods of time that, due to the variability of commodity prices and compressed margins, we reduce or cease ethanol production operations at certain of our ethanol plants. In the first nine months of 2012, we reduced production volumes at several of our ethanol plants by approximately 8% of our total production in direct response to unfavorable operating margins.

 

Reduced Availability of Capital.  Some ethanol producers have faced financial distress over the past few years, culminating with bankruptcy filings by several companies. This, in combination with continued volatility in the capital markets, has resulted in reduced availability of capital for the ethanol industry in general. In this market environment, we may experience limited access to incremental financing.

 

Legislation.  Federal and state governments have enacted numerous policies, incentives and subsidies to encourage the usage of domestically-produced alternative fuel solutions. Passed in 2007 as part of the Energy Independence and Security Act, RFS II has been, and we expect will continue to be, a driving factor in the growth of ethanol usage. The RFS Flexibility Act was introduced on October 5, 2011 in the U.S. House of Representatives to reduce or eliminate the volumes of renewable fuel use required by RFS II based upon corn stocks-to-use ratios. The Domestic Alternative Fuels Act of 2012 was introduced on January 18, 2012 in the U.S. House of Representatives to modify the RFS II to include ethanol and other fuels produced from fossil fuels like coal and natural gas. Due to drought conditions, the possibility of further legislation aimed at reducing or eliminating the renewable fuel use required by RFS II may also be heightened. 

 

Under the provisions of the Energy Independence and Security Act, the EPA has the authority to waive the mandated RFS II requirements in whole or in part. To grant the waiver, the EPA administrator must determine, in consultation with the Secretaries of Agriculture and Energy, that one of two conditions has been met: (1) there is inadequate domestic renewable

27

 


 

 

fuel supply or (2) implementation of the requirement would severely harm the economy or environment of a state, a region, or the U.S. In the third quarter of 2012, the governors of North Carolina and Arkansas as well as a number of livestock groups filed waiver requests with the EPA based on drought conditions. On August 20, 2012 the EPA asked for public comment on the need for an ethanol waiver. The agency has until November 13, 2012 to make a decision regarding the requested waiver. We believe it is unlikely the EPA will grant the requested waiver. However, our operations could be adversely impacted if a waiver is granted.

 

To further drive growth in the increased adoption of ethanol, Growth Energy, an ethanol industry trade association, and a number of ethanol producers requested a waiver from the EPA to increase the allowable amount of ethanol blended into gasoline from the current 10% level, or E10, to a 15% level, or E15. In October 2010, the EPA granted a partial waiver for E15 for use in model year 2007 and newer model passenger vehicles, including cars, SUVs, and light pickup truck. In January 2011, the EPA granted a second partial waiver for E15 for use in model year 2001 to 2006 passenger vehicles. On February 17, 2012, the EPA announced that evaluation of the health effects tests of E15 are complete and that fuel manufacturers are now able to register E15 with the EPA to sell. To meet one of the final requirements of the EPA prior to introducing E15 into the marketplace, in April 2012, a group of ethanol industry members funded a national fuel survey on E15. In June 2012, the EPA gave final approval for the sale and use of E15 ethanol blends in light duty vehicles made since 2001, representing nearly two-thirds of all vehicles on the road. The nation’s first retail E15 ethanol blends were sold in July  2012. According to the EPA, as of September 28, 2012, 75 fuel manufacturers were registered to sell E15.

 

On July 21, 2010, President Obama signed the Dodd-Frank Wall Street Reform and Consumer Protection Act, or the Reform Act, which, among other things, aims to improve transparency and accountability in derivative markets. While the Reform Act increases the regulatory authority of the Commodity Futures Trading Commission, or CFTC, regarding over-the-counter derivatives, there is uncertainty on several issues related to market clearing, definitions of market participants, reporting, and capital requirements. While many details remain to be addressed in CFTC rulemaking proceedings, at this time we do not anticipate any material impact to our risk management strategy. 

 

Industry Fundamentals. The ethanol industry is supported by a number of market fundamentals that drive its long-term outlook and extend beyond the short-term margin environment. Following the EPA’s approval, the industry is working to broadly introduce E15 into the retail fuel market. The RFS II mandate increased to 13.2 billion gallons for 2012, 600 million gallons over the mandated volume in 2011, and continues to increase each year through 2015; however, the EPA has the authority to waive the mandate in whole or in part. The domestic gasoline market continues to evolve as refiners are producing more CBOB, a sub-grade (84 octane) gasoline, which requires ethanol or other octane sources to meet the minimum octane rating requirements for the U.S. gasoline market. In addition, ethanol export markets, although affected by competition from other ethanol exporters, mainly from Brazil, are expected to remain active in 2012. Overall, the industry is operating at the mandated levels and ethanol prices have continued to remain at a large discount to gasoline, providing blenders and refiners with a strong economic incentive to blend.

 

BioProcess Algae Joint Venture

 

The BioProcess Algae joint venture is focused on developing technology to grow and harvest algae, which consume carbon dioxide, in commercially viable quantities. Construction of Phase II next to our Shenandoah ethanol plant was completed and the Grower Harvesters™ bioreactors were successfully started up in January 2011. Phase II allowed for verification of growth rates, energy balances and operating expenses, which are considered to be some of the key steps to commercialization. In April 2012, we increased our ownership of BioProcess Algae to 49% pursuant to our purchase of ownership interests previously held by NTR plc.

 

In June 2012, BioProcess Algae and a subsidiary of Bioseutica BV, a leading producer of highly purified pharmaceutical-grade Omega-3 fatty acids, entered into a commercial supply agreement for the production of EPA-rich Omega-3 oils for use in nutritional or pharmaceutical applications. BioProcess Algae continues to explore additional potential algae markets including animal feeds, nutraceuticals and biofuels. 

 

BioProcess Algae initiated Phase III and broke ground on a five-acre algae farm at the Shenandoah ethanol plant in the first quarter of 2012. Construction is complete on approximately three acres of the algae farm and the facilities were inoculated with algae in October 2012. If we and the other BioProcess Algae members determine that the venture can achieve the desired economic performance from Phase III, a larger build-out, possibly as large as 200 to 400 acres, of Grower Harvester reactors at the Shenandoah ethanol plant will be considered. Such a build-out may be completed in stages and could take up to two years to complete. Funding for BioProcess Algae for such a project would come from a variety of sources including current partners, new equity investors, debt financing or a combination thereof.

 

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Critical Accounting Policies and Estimates

 

This disclosure is based upon our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The preparation of these financial statements requires that we make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. We base our estimates on historical experience and other assumptions that we believe are proper and reasonable under the circumstances. We continually evaluate the appropriateness of estimates and assumptions used in the preparation of our consolidated financial statements. Actual results could differ materially from those estimates. Key accounting policies, including but not limited to those relating to revenue recognition, property and equipment, impairment of long-lived assets and goodwill, derivative financial instruments, and accounting for income taxes, are impacted significantly by judgments, assumptions and estimates used in the preparation of the consolidated financial statements. See further discussion of our critical accounting policies and estimates, as well as significant accounting policies, in our annual report on Form 10-K for the year ended December 31, 2011.

 

Recent Accounting Pronouncements

 

Effective January 1, 2012, we adopted the third phase of amended guidance in ASC Topic 820, Fair Value Measurements and Disclosures. The amended guidance clarifies the application of existing fair value measurement requirements and requires additional disclosure for Level 3 measurements regarding the sensitivity of fair value to changes in unobservable inputs and any interrelationships between those inputs. We currently are not impacted by the additional disclosure requirements as we do not have any recurring Level 3 measurements.

 

Effective January 1, 2012, we adopted the amended guidance in ASC Topic 220, Comprehensive Income. The amended guidance is aimed at increasing the prominence of other comprehensive income in the financial statements by eliminating the option to present other comprehensive income in the statement of stockholders’ equity. We elected to present net income and other comprehensive income in two separate but consecutive statements. The updated presentation, which has been implemented retroactively for all comparable periods presented, did not impact our financial position or results of operations.

 

Effective January 1, 2012, we adopted the amended guidance in ASC Topic 350, Intangibles – Goodwill and Other. The amended guidance permits an entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether it is necessary to perform the two-step goodwill impairment test. The amended guidance did not impact our disclosure or reporting requirements.

 

Off-Balance Sheet Arrangements

 

We do not have any off-balance sheet arrangements that have or are reasonably likely to have a current or future material effect on our consolidated financial condition, results of operations or liquidity.

 

Components of Revenues and Expenses

 

Revenues.  In our ethanol production segment, our revenues are derived primarily from the sale of ethanol and distillers grains, which is a co-product of the ethanol production process. In our corn oil production segment, our revenues are derived from the sale of corn oil, which is extracted from the whole stillage immediately prior to the production of distillers grains. In our agribusiness segment, the sale of grain, fertilizer and petroleum products are our primary sources of revenue. In our marketing and distribution segment, the sale of ethanol, distillers grains and corn oil that we market for our nine ethanol plants, the sale of ethanol we market for third-party ethanol plants and the sale of other commodities purchased in the open market represent our primary sources of revenue. Revenues also include net gains or losses from derivatives.

 

Cost of Goods Sold.    Cost of goods sold in our ethanol production and corn oil production segments includes costs for direct labor, materials and certain plant overhead costs. Direct labor includes all compensation and related benefits of non-management personnel involved in the operation of our ethanol plants. Plant overhead costs primarily consist of plant utilities, plant depreciation and outbound freight charges. Our cost of goods sold is mainly affected by the cost of ethanol, corn, natural gas and transportation. In these segments, corn is our most significant raw material cost. We purchase natural gas to power steam generation in our ethanol production process and to dry our distillers grains. Natural gas represents our second largest cost in this business segment. Cost of goods sold also includes net gains or losses from derivatives.

 

Grain, fertilizer and petroleum acquisition costs represent the primary components of cost of goods sold in our agribusiness segment. Grain inventories, forward purchase contracts and forward sale contracts are valued at market prices, where available, or other market quotes adjusted for differences, primarily transportation, between the exchange-traded

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market and the local markets on which the terms of the contracts are based. Changes in the market value of grain inventories, forward purchase and sale contracts, and exchange-traded futures and options contracts are recognized in earnings as a component of cost of goods sold.

 

In our marketing and distribution segment, purchases of ethanol, distillers grains and corn oil represent the largest components of cost of goods sold. Transportation expense represents an additional major component of our cost of goods sold in this segment. Transportation expense includes rail car leases, freight and shipping of our ethanol and co-products, as well as costs incurred in storing ethanol at destination terminals.

 

Selling, General and Administrative Expenses.  Selling, general and administrative expenses are recognized at the operating segment level, as well as at the corporate level. These expenses consist of employee salaries, incentives and benefits; office expenses; board fees; and professional fees for accounting, legal, consulting, and investor relations activities. Personnel costs, which include employee salaries, incentives and benefits, are the largest single category of expenditures in selling, general and administrative expenses. We refer to selling, general and administrative expenses that are not allocable to a segment as corporate activities.

 

Other Income (Expense).    Other income (expense) includes interest earned, interest expense and other non-operating items.

 

Results of Operations 

 

Segment Results

 

Our operations fall within the following four segments: (1) production of ethanol and related distillers grains, collectively referred to as ethanol production, (2) corn oil production, (3) grain warehousing and marketing, as well as sales and related services of agronomy and petroleum products, collectively referred to as agribusiness, and (4) marketing and logistics services of Company-produced and third-party ethanol, distillers grains, corn oil and other commodities, and the operation of blending and terminaling facilities, collectively referred to as marketing and distribution. Selling, general and administrative expenses, primarily consisting of compensation of corporate employees, professional fees and overhead costs not directly related to a specific operating segment, are reflected in the table below as corporate activities. When the Company’s management evaluates segment performance, they review the information provided below, as well as segment earnings before interest, income taxes, noncontrolling interest, depreciation and amortization.

 

During the normal course of business, our operating segments enter into transactions with one another. For example, our ethanol production and corn oil production segments sell ethanol, distillers grains and corn oil to our marketing and distribution segment and our agribusiness segment sells grain to our ethanol production segment. These intersegment activities are recorded by each segment at prices approximating market and treated as if they are third-party transactions. Consequently, these transactions impact segment performance. However, intersegment revenues and corresponding costs are eliminated in consolidation, and do not impact our consolidated results.

 

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The table below reflects selected operating segment financial information for the periods indicated (in thousands):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended
September 30,

 

Nine Months Ended
September 30,

 

 

2012

 

2011

 

2012

 

2011

Revenues:

 

 

 

 

 

 

 

 

 

 

 

 

Ethanol production:

 

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

$

52,982 

 

$

35,077 

 

$

149,115 

 

$

97,377 

Intersegment revenues

 

 

439,917 

 

 

551,987 

 

 

1,268,851 

 

 

1,501,031 

Total segment revenues

 

 

492,899 

 

 

587,064 

 

 

1,417,966 

 

 

1,598,408 

Corn oil production:

 

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

 

 

 

393 

 

 

518 

 

 

1,464 

Intersegment revenues

 

 

14,530 

 

 

15,115 

 

 

43,003 

 

 

28,886 

Total segment revenues

 

 

14,531 

 

 

15,508 

 

 

43,521 

 

 

30,350 

Agribusiness:

 

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

 

125,446 

 

 

95,065 

 

 

300,051 

 

 

233,959 

Intersegment revenues

 

 

50,254 

 

 

48,863 

 

 

134,725 

 

 

149,676 

Total segment revenues

 

 

175,700 

 

 

143,928 

 

 

434,776 

 

 

383,635 

Marketing and distribution:

 

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

 

768,984 

 

 

826,483 

 

 

2,143,479 

 

 

2,298,121 

Intersegment revenues

 

 

111 

 

 

98 

 

 

302 

 

 

375 

Total segment revenues

 

 

769,095 

 

 

826,581 

 

 

2,143,781 

 

 

2,298,496 

Revenues including intersegment activity

 

 

1,452,225 

 

 

1,573,081 

 

 

4,040,044 

 

 

4,310,889 

Intersegment eliminations

 

 

(504,812)

 

 

(616,063)

 

 

(1,446,881)

 

 

(1,679,968)

Revenues as reported

 

$

947,413 

 

$

957,018 

 

$

2,593,163 

 

$

2,630,921 

Gross profit (loss):

 

 

 

 

 

 

 

 

 

 

 

 

Ethanol production

 

$

(3,701)

 

$

24,846 

 

$

(20,610)

 

$

63,880 

Corn oil production

 

 

7,865 

 

 

9,642 

 

 

25,205 

 

 

18,098 

Agribusiness

 

 

12,513 

 

 

8,223 

 

 

27,357 

 

 

20,425 

Marketing and distribution

 

 

10,980 

 

 

5,069 

 

 

21,769 

 

 

17,332 

Intersegment eliminations

 

 

240 

 

 

(487)

 

 

1,079 

 

 

444 

 

 

$

27,897 

 

$

47,293 

 

$

54,800 

 

$

120,179 

Operating income (loss):

 

 

 

 

 

 

 

 

 

 

 

 

Ethanol production

 

$

(7,520)

 

$

20,941 

 

$

(32,435)

 

$

52,184 

Corn oil production

 

 

7,811 

 

 

9,632 

 

 

25,011 

 

 

18,040 

Agribusiness

 

 

5,849 

 

 

2,151 

 

 

8,916 

 

 

3,934 

Marketing and distribution

 

 

7,162 

 

 

1,923 

 

 

10,546 

 

 

7,078 

Intersegment eliminations

 

 

240 

 

 

(481)

 

 

1,113 

 

 

474 

Corporate activities

 

 

(4,918)

 

 

(5,121)

 

 

(16,701)

 

 

(14,881)

 

 

$

8,624 

 

$

29,045 

 

$

(3,550)

 

$

66,829 

 

 

 

Three Months Ended September 30, 2012 Compared to the Three Months Ended September 30, 2011

 

Consolidated Results

 

Revenues decreased $9.6 million for the three months ended September 30, 2012 compared to the same period in 2011 primarily due to lower average prices of ethanol and corn oil and lower volumes of distillers grains sold partially offset by increased revenues from grain merchandising.  Revenues from grain merchandising increased primarily due to higher grain prices in 2012 and the impacts of an early harvest in our market areas.  The 2012 drought resulted in increases in commodity prices and an early harvest season, which is affecting the expected timing of revenues from historical patterns between the third and fourth quarters. Gross profit decreased $19.4 million for the three months ended September 30, 2012 compared to the same period in 2011 primarily as a result of unfavorable ethanol production margins. Operating income decreased $20.4 million in the three months ended September 30, 2012 compared to the same period in 2011 as a result of the factors discussed above. Selling, general and administrative expenses increased slightly when comparing the three months ended September 30, 2012 to the same period in 2011 due to the expanded scope of our operations.  As a result of our net loss, we

31

 


 

 

recorded an income tax benefit of $0.6 million for the three months ended September 30, 2012 compared to income tax expense of $7.0 million for the same period in 2011.

 

The following discussion of segment results provides greater detail on period-to-period results.

 

Ethanol Production Segment

 

The table below presents key operating data within our ethanol production segment for the periods indicated:

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

September 30,

 

 

2012

 

2011

Ethanol sold

 

 

 

 

(thousands of gallons)

 

161,574 

 

184,619 

Ethanol produced

 

 

 

 

(thousands of gallons)

 

160,832 

 

185,928 

Distillers grains sold

 

 

 

 

(thousands of equivalent dried tons)

 

438 

 

534 

Corn consumed

 

 

 

 

(thousands of bushels)

 

56,706 

 

65,896 

 

Revenues in the ethanol production segment decreased by $94.2 million for the three months ended September 30, 2012 compared to the same period in 2011. The decrease in revenue was due to lower average prices for ethanol and the decision, in direct response to unfavorable operating margins, to temporarily reduce production at our ethanol plants.  The ethanol production segment produced 160.8 million gallons of ethanol, which represents approximately 87 percent of production capacity, during the three months ended September 30, 2012.

 

Cost of goods sold in the ethanol production segment decreased by $65.6 million for the three months ended September 30, 2012 compared to the same period in 2011. Consumption of corn decreased by 9.2 million bushels and the average cost per bushel increased by 10.2% during the three months ended September 30, 2012 compared to the same period in 2011. Average ethanol yield increased to 2.84 gallons per bushel for the three months ended September 30, 2012 compared to 2.82 gallons per bushel in the same period of 2011 due primarily to process improvements implemented and slowed production rates at some of our plants. As a result of the factors identified above, gross profit and operating income in the ethanol production segment decreased by $28.5 million for the three months ended September 30, 2012, compared to the same period in 2011, resulting in an operating loss of $7.5 million.  

 

Corn Oil Production Segment

 

Revenues in the corn oil production segment decreased by $1.0 million for the three months ended September 30, 2012 compared to the same period in 2011. During the three months ended September 30, 2012, we sold 37.2 million pounds of corn oil compared to 32.7 million pounds in the same period of 2011. The increase in volume was offset by a 16% decrease in average price for the three months ended September 30, 2012 compared to the same period in 2011. Average corn oil yield increased to 0.66 pounds per bushel for the three months ended September 30, 2012 compared to 0.50 pounds per bushel in the same period in 2011 due primarily to process improvements implemented at our plants. We began extracting corn oil in the fourth quarter of 2010 with the last implementation, which was at the Otter Tail plant, completed during the third quarter of 2011.

 

Gross profit and operating income in the corn oil production segment decreased by $1.8 million for the three months ended September 30, 2012 compared to the same period in 2011. The decreases are primarily attributable to a decrease in average revenue per pound, partially offset by improved corn oil yields.

 

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Agribusiness Segment

 

The table below presents key operating data within our agribusiness segment for the periods indicated:

 

 

 

 

 

 

 

 

 

Three Months Ended

September 30,

 

 

2012

 

2011

Grain sold

 

 

 

 

(thousands of bushels)

 

18,864 

 

24,320 

Fertilizer sold

 

 

 

 

(tons)

 

3,084 

 

790 

 

Our agribusiness segment had increases of  $31.8 million in revenues, $4.3 million in gross profit and $3.7 in operating income for the three months ended September 30, 2012 compared to the same period in 2011. Revenues, gross profit and operating income increased primarily due to higher grain prices in 2012. The 2012 drought resulted in increased commodity prices and an early harvest season which is affecting the expected timing of gross profit between the third and fourth quarters. Operating income was also affected by an increase in selling, general and administrative expenses due to the expanded scope of our agribusiness operations, through construction of grain storage capacity and the acquisition of a grain elevator in January 2012. The agribusiness segment’s quarterly performance fluctuates on a seasonal basis with generally stronger results expected in the second and fourth quarters each year; however, the effects of the early harvest in our market areas has accelerated some of the expected agribusiness results for 2012 into the third quarter. 

 

Marketing and Distribution Segment

 

Revenues in our marketing and distribution segment decreased by $57.5 million for the three months ended September 30, 2012 compared to the same period in 2011. The decrease in revenues was primarily due to lower average prices of ethanol and corn oil and lower volumes of distillers grains sold. Ethanol and distillers grains revenues decreased by $58.2 million and $13.8 million, respectively, partially offset by an increase in other revenues of $14.4 million. In the three months ended September 30, 2012, the marketing and distribution segment entered into purchases and sales of crude oil and leased railcars to third parties for the transportation of crude oil. Railcar leasing and crude oil revenue for the three months ended September 30, 2012 was $18.2 million. We sold 267.5 million gallons of ethanol within the marketing and distribution segment during the three months ended September 30, 2012 compared to 265.4 million gallons sold during the same period in 2011. Ethanol volumes increased due to an increase in open-market ethanol purchases and sales. However, the decrease in average prices of ethanol offset the increase in volumes resulting in a net decrease in ethanol revenues.

 

Gross profit and operating income for the marketing and distribution segment increased by $5.9 million and $5.2 million, respectively, for the three months ended September 30, 2012 compared to the same period in 2011. The increases in gross profit and operating income were due primarily to profits realized from ethanol, distillers grains and crude oil marketing and distribution.  

 

Intersegment Eliminations

 

Intersegment eliminations of revenues decreased $111.3 million for the three months ended September 30, 2012 compared to the same period in 2011 due to decreases of $102.3 million, $9.7 and $0.6 million in ethanol, distillers grains and corn oil, respectively, sold from our ethanol production and corn oil segments to our marketing and distribution segment. In addition, corn sales from our agribusiness segment increased $1.5 million between the periods.

 

Corporate Activities

 

Operating expenses for corporate activities were consistent when comparing the three months ended September 30, 2012 to the same period in 2011. No significant changes were made to the scope of our operations that affected these periods.

 

Income Taxes

 

We record income tax expense or benefit during interim periods based on our best estimate of the annual effective tax rate. We recorded an income tax benefit of $0.6 million for the three months ended September 30, 2012 compared to income tax expense of $7.0 million for the same period in 2011. The effective tax rate (calculated as the ratio of income tax expense to income before income taxes) was slightly higher in the third quarter of 2012 compared to the same period of 2011. 

 

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Nine Months Ended September 30, 2012 Compared to the Nine Months Ended September 30, 2011

 

Consolidated Results

 

Revenues decreased $37.8 million for the nine months ended September 30, 2012 compared to the same period in 2011 as a result of lower average ethanol and corn oil prices and lower volumes of distillers grains sold partially offset by increased revenues from grain merchandising.  Agribusiness revenues increased primarily due to higher grain prices in 2012 and the impacts of an early harvest in our market areas.  The 2012 drought resulted in increases in grain prices and an early harvest season, which is affecting the expected timing of revenues from historical patterns between the third and fourth quarters. Gross profit decreased $65.4 million for the nine months ended September 30, 2012 compared to the same period in 2011 primarily as a result of unfavorable ethanol production margins. Operating income decreased $70.4 million to an operating loss of $3.6 million in the nine months ended September 30, 2012 compared to the same period in 2011 as a result of the factors discussed above. Selling, general and administrative expenses were $5.0 million higher for the nine months ended September 30, 2012 compared to the same period in 2011 due to the expanded scope of our operations which resulted primarily from our acquisition of the Otter Tail ethanol plant in March 2011. Interest expense increased by $1.3 million in the first nine months of 2012 compared to the same period in 2011 due to debt issued to finance the acquisition. As a result of our net loss, we recorded an income tax benefit of $12.7 million for the nine months ended September 30, 2012 compared to income tax expense of $14.2 million for the same period in 2011.

 

The following discussion of segment results provides greater detail on period-to-period results.

 

Ethanol Production Segment

 

The table below presents key operating data within our ethanol production segment for the periods indicated:

 

 

 

 

 

 

 

 

 

 

 

 

Nine Months Ended

September 30,

 

 

2012

 

2011

Ethanol sold

 

 

 

 

(thousands of gallons)

 

507,923 

 

540,638 

Ethanol produced

 

 

 

 

(thousands of gallons)

 

508,358 

 

540,686 

Distillers grains sold

 

 

 

 

(thousands of equivalent dried tons)

 

1,397 

 

1,536 

Corn consumed

 

 

 

 

(thousands of bushels)

 

178,924 

 

190,933 

Revenues in the ethanol production segment decreased by $180.4 million for the nine months ended September 30, 2012 compared to the same period in 2011. The decrease in revenue was due to the decision, in direct response to unfavorable operating margins, to temporarily reduce ethanol production volumes at our ethanol plants and due to lower average prices for ethanol during the nine months ended September 30, 2012 compared to the same period in 2011. The ethanol production segment produced 508.4 million gallons of ethanol, which represents approximately 92 percent of production capacity, during the first nine months of 2012. Revenues for the nine months ended September 30, 2012 included production from our Otter Tail ethanol plant, which was acquired in March 2011. The Otter Tail plant contributed an additional $7.3 million in revenues for the nine months ended September 30, 2012 compared to the same period in 2011.

 

Cost of goods sold in the ethanol production segment decreased by $96.0 million for the nine months ended September 30, 2012 compared to the same period in 2011. Consumption of corn decreased by 12.0 million bushels and the average cost per bushel increased by 1.3% during the nine months ended September 30, 2012 compared to the same period in 2011. Average ethanol yield increased to 2.84 gallons per bushel for the nine months ended September 30, 2012 compared to 2.83 gallons per bushel in the same period of 2011, due primarily to process improvements implemented and slowed production rates at some of our plants. Cost of goods sold also included a one-time charge related to the settlement of a legal claim in the first quarter of 2012. As a result of the factors identified above, gross profit for the ethanol production segment decreased by $84.5 million for the nine months ended September 30, 2012 compared to the same period in 2011.

 

Operating income in the ethanol production segment decreased by $84.6 million for the nine months ended September 30, 2012, compared to the same period in 2011, to a loss of $32.4 million, due in large part to the factors discussed above. Depreciation and amortization expense for the ethanol production segment was $33.3 million during the nine months ended September 30, 2012 compared to $32.0 million during the same period in 2011.

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Corn Oil Production Segment

 

Revenues in the corn oil production segment increased by $13.2 million for the nine months ended September 30, 2012 compared to the same period in 2011. During the nine months ended September 30, 2012, we sold 109.2 million pounds of corn oil compared to 64.3 million pounds in the same period of 2011. The increase in volume was offset by a 14% decrease in average price in the first nine months of 2012 compared to the same period in 2011. We began extracting corn oil in the fourth quarter of 2010 and had deployed corn oil extraction technology at four of our ethanol plants by December 31, 2010. In 2011, we began extracting corn oil at our other five ethanol plants with the last implementation, which was at the Otter Tail plant completed during the third quarter of 2011.

 

Gross profit and operating income in the corn oil production segment increased by $7.1 million and $7.0 million, respectively, for the nine months ended September 30, 2012 compared to the same period in 2011. The increases are primarily attributable to the increase in production volumes discussed above.

 

Agribusiness Segment

 

The table below presents key operating data within our agribusiness segment for the periods indicated:

 

 

 

 

 

 

 

 

 

Nine Months Ended

September 30,

 

 

2012

 

2011

Grain sold

 

 

 

 

(thousands of bushels)

 

48,367 

 

51,639 

Fertilizer sold

 

 

 

 

(tons)

 

35,126 

 

33,801 

 

Our agribusiness segment had increases of $51.1 million in revenues, $6.9 million in gross profit, and $5.0 million in operating income for the nine months ended September 30, 2012 compared to the same period in 2011. Revenues, gross profit and operating income increased primarily due to higher grain prices in 2012. The 2012 drought resulted in increased commodity prices and an early harvest season, which is affecting the expected timing of gross profits between the third and fourth quarters. Operating income was also affected by an increase in selling, general and administrative expenses due to the expanded scope of our agribusiness operations, through construction of grain storage capacity and the acquisition of two grain elevators in June 2011 and January 2012. The agribusiness segment’s quarterly performance fluctuates on a seasonal basis with generally stronger results expected in the second and fourth quarters each year;  however, the effects of the early harvest in our market areas has accelerated some of the expected agribusiness results for 2012 into the third quarter. 

 

Marketing and Distribution Segment

 

Revenues in our marketing and distribution segment decreased by $154.7 million for the nine months ended September 30, 2012 compared to the same period in 2011. The decrease in revenues was primarily due to lower average prices of ethanol and corn oil sold and lower volumes of distillers grains sold. Ethanol and distillers grains revenues decreased by $188.2 million and $14.9 million, respectively, partially offset by increases in corn oil and crude oil revenues of $15.0 million and $35.9 million, respectively. We sold 804.5 million gallons of ethanol within the marketing and distribution segment during the nine months ended September 30, 2012 and 2011.  In the first nine months of 2012, the marketing and distribution segment also entered into purchases and sales of crude oil and redeployed a portion of its railcar fleet for the transportation or crude oil by third parties.  

 

Gross profit and operating income for the marketing and distribution segment increased $4.4 million and $3.5 million, respectively, for the nine months ended September 30, 2012 compared to the same period in 2011. The increases in gross profit and operating income were due primarily to profits realized from ethanol, distillers grains and crude oil marketing and distribution. 

 

Intersegment Eliminations

 

Intersegment eliminations of revenues decreased $233.1 million for the nine months ended September 30, 2012 compared to the same period in 2011 due to a decreases of $225.9 million and $6.3 million in ethanol and distillers grains, respectively, and an increase of  $14.1 million in corn oil sold from our ethanol production and corn oil segments to our marketing and distribution segment. In addition, corn sales from our agribusiness segment decreased $14.9 million between the periods.

35

 


 

 

 

Corporate Activities

 

Operating income was impacted by an increase in operating expenses for corporate activities of $1.8 million for the nine months ended September 30, 2012 compared to the same period in 2011, primarily due to an increase in general and administrative expenses and personnel costs related to expanded operations.

 

Income Taxes

 

We record income tax expense or benefit during interim periods based on our best estimate of the annual effective tax rate. We recorded an income tax benefit of $12.7 million for the nine months ended September 30, 2012 compared to income tax expense of $14.2 million for the same period in 2011. The effective tax rate (calculated as the ratio of income tax expense to income before income taxes) was approximately 37.5% and 36.3% for the first nine months of 2012 and 2011, respectively. The effective tax rate for the first nine months of 2011 reflects the release of a portion of valuation allowances provided against certain of our deferred tax assets, primarily federal and state net operating losses and tax credits.

 

EBITDA

 

Management uses earnings before interest, income taxes, noncontrolling interests, depreciation and amortization, or EBITDA, to measure our financial performance and to internally manage our businesses. Management believes that EBITDA provides useful information to investors as a measure of comparison with peer and other companies. EBITDA should not be considered an alternative to, or more meaningful than, net income or cash flow as determined in accordance with generally accepted accounting principles. EBITDA calculations may vary from company to company. Accordingly, our computation of EBITDA may not be comparable with a similarly titled measure of another company. The following sets forth the reconciliation of net income (loss) to EBITDA for the periods indicated (in thousands):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

September 30,

 

Nine Months Ended

September 30,

 

2012

 

2011

 

2012

 

2011

Net income (loss) attributable to Green Plains

$

(1,002)

 

$

12,429 

 

$

(21,244)

 

$

25,152 

Net loss attributable to noncontrolling interests

 

(4)

 

 

(28)

 

 

(13)

 

 

(200)

Interest expense

 

9,832 

 

 

9,440 

 

 

28,741 

 

 

27,438 

Income tax expense (benefit)

 

(604)

 

 

6,979 

 

 

(12,749)

 

 

14,191 

Depreciation and amortization

 

13,487 

 

 

12,811 

 

 

39,922 

 

 

36,848 

EBITDA

$

21,709 

 

$

41,631 

 

$

34,657 

 

$

103,429 

 

 

 

Liquidity and Capital Resources

 

On September 30, 2012, we had $140.2 million in cash and equivalents, comprised of $71.0 million held at our parent company and the remainder at our subsidiaries. We also had up to an additional $154.5 million available under revolving credit agreements at our subsidiaries, some of which was subject to borrowing base restrictions or other specified lending conditions at September 30, 2012. Funds held at our subsidiaries are generally required for their ongoing operational needs and distributions from our subsidiaries are restricted pursuant to these loan agreements. At September 30, 2012, there were approximately $475.4 million of net assets at our subsidiaries that were not available to be transferred to the parent company in the form of dividends, loans or advances due to restrictions contained in the credit facilities of these subsidiaries.

 

We incurred capital expenditures of $23.9 million in the first nine months of 2012 for various projects including the construction of a new BlendStar unit train terminal in Birmingham, Alabama, which is expected to be completed and operational in the fourth quarter of 2012. Capital spending for the remainder of 2012 is expected to be approximately $5.0 million which includes expansion of the grain storage facilities at some of our ethanol plants. The remainder of our capital spending is expected to be financed with available borrowings under our credit facilities and cash provided by operating activities.

 

Net cash used by operating activities was $15.5 million for the nine months ended September 30, 2012 compared to net cash provided of $15.9 million for the same period in 2011. Cash used by operating activities for the nine months ended September 30, 2012 and 2011 included significant cash outflows for deferred grain contract payables, inventory purchases and a reduction in unearned revenues within our agribusiness segment. Additional factors affecting the net cash used by operating activities during the nine months ended September 30, 2012 included a net loss of $21.3 million. Net cash used by

36

 


 

 

investing activities was $31.9 million for the nine months ended September 30, 2012, due primarily to capital expenditures and the increase of our ownership interest in BioProcess Algae from 35% to 49%. Net cash provided by financing activities was $12.6 million for the nine months ended September 30, 2012 due to a net increase in short-term notes payable and inventory financing arrangements of $57.6 million, used to finance grain contract settlements and inventory purchases, partially offset by $10.4 million in cash outflows for the repurchase of treasury stock and principal proceeds and repayments on long-term debt of $53.2 million and $87.7 million, respectively, in the first nine months of 2012. Green Plains Trade and Green Plains Grain utilize revolving credit facilities to finance working capital requirements. These facilities are frequently drawn upon and repaid resulting in significant cash movements that are reflected on a gross basis within financing activities as proceeds from and payments on short-term borrowings.

 

Our business is highly impacted by commodity prices, including prices for corn, ethanol, distillers grains and natural gas. We attempt to reduce the market risk associated with fluctuations in commodity prices through the use of derivative financial instruments. Sudden changes in commodity prices may require cash deposits with brokers, or margin calls. Depending on our open derivative positions, we may require significant liquidity with little advanced notice to meet margin calls. We continuously monitor our exposure to margin calls and believe that we will continue to maintain adequate liquidity to cover such margin calls from operating results and borrowings. Recent increases in grain prices and our expanded grain handling capacity have led to more frequent and larger margin calls.

 

We were in compliance with our debt covenants at September 30, 2012. Based upon our forecasts and the current margin environment, we believe certain ethanol production subsidiaries will require capital injections from the parent company at times to maintain compliance with certain covenants during the remainder of 2012. We believe we will maintain compliance with our debt covenants at each of our subsidiaries for the upcoming twelve months, or if necessary have sufficient liquidity available at the parent company to resolve a subsidiary’s noncompliance; however, no obligation exists to provide such liquidity for a subsidiary’s compliance. No assurance can be provided that actual operating results will approximate our forecasts or that we will inject the necessary capital into a subsidiary to maintain compliance with its respective covenants. In the event actual results differ significantly from our forecasts and a subsidiary is unable to comply with its respective debt covenants, the subsidiary’s lenders may determine that an event of default has occurred. Upon the occurrence of an event of default, and following notice, the lenders may terminate any commitment and declare the entire unpaid balance due and payable.

 

We believe that we have sufficient working capital for our existing operations. However, we can provide no assurance that we will be able to secure additional funding for our future operations. A sustained period of unprofitable operations may strain our liquidity and make it difficult to maintain compliance with our financing arrangements. While we may seek additional sources of working capital in response, we can provide no assurance that we will be able to secure this funding if necessary. We may sell additional equity or borrow additional amounts to improve or preserve our liquidity; expand our existing businesses; or build additional or acquire existing businesses. We can provide no assurance that we will be able to secure the funding necessary for these additional projects or for additional working capital needs at reasonable terms, if at all.

 

On October 26, 2012, we entered into an asset purchase agreement to sell approximately 32.6 million bushels, or 83%, of our reported agribusiness grain storage capacity and all of our agronomy and retail petroleum operations. The estimated sales price for the facilities and certain related working capital is $133.1 million, including the assumption at closing of term debt of approximately $28.3 million. In addition, the Company expects to realize net proceeds from the liquidation of retained working capital of approximately $86.7 million before the repayment of approximately $85.2 million under a revolving credit facility and inventory financing arrangements. Working capital and amounts outstanding under debt and inventory financing arrangements are based on September 30, 2012 balances and will be adjusted to final amounts at closing. Net cash proceeds, including working capital liquidation, are expected to be approximately $103.8 million.

 

Debt

 

For additional information related to our debt, see Note 7 – Debt included herein as part of the Notes to Consolidated Financial Statements and Note 10 – Debt included as part of the Notes to Consolidated Financial Statements included in our annual report on Form 10-K for the year ended December 31, 2011.

 

Ethanol Production Segment

 

Each of our ethanol production segment subsidiaries have credit facilities with lender groups that provide for term and revolving term loans to finance construction and operation of the production facilities.

 

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The Green Plains Bluffton loan is comprised of a $70.0 million amortizing term loan and a $20.0 million revolving term loan. At September 30, 2012,  $42.8 million related to the term loan was outstanding, along with the entire revolving term loan. The term loan requires monthly principal payments of approximately $0.6 million. The loans mature on November 19, 2013 with expected outstanding balances upon maturity of $34.6 million and $20.0 million on the amortizing term loan and revolving term loan, respectively. We expect to extend or refinance this facility prior to its maturity.

 

The Green Plains Central City loan is comprised of a $55.0 million amortizing term loan and a $30.5 million revolving term loan as well as a revolving line of credit of up to $11.0 million. At September 30, 2012, $40.0 million related to the term loan was outstanding, along with $27.7 million on the revolving term loan and $10.0 million on the revolving line of credit. The term loan requires monthly principal payments of $0.5 million. The term loan and the revolving term loan mature on July 1, 2016 with expected outstanding balances upon maturity of $17.9 million and $27.7 million, respectively, and the revolving line of credit matures on June 27, 2013. We expect to extend or refinance the revolving credit facility prior to its maturity.

 

The Green Plains Holdings II loan is comprised of a $26.4 million amortizing term loan and a $51.1 million revolving term loan. At September 30, 2012, $23.4 million was outstanding on the amortizing term loan, along with $48.0 million on the revolving term loan. The term loan requires quarterly principal payments of $1.5 million. The revolving term loan requires semi-annual principal payments of approximately $2.7 million. The maturity dates of the amortizing term loan and revolving term loan are July 1, 2016 and October 1, 2018, respectively, with no outstanding balance expected upon maturity on the amortizing term loan and an expected outstanding balance upon maturity of $15.8 million on the revolving term loan.

 

The Green Plains Obion loan is comprised of a $60.0 million amortizing term loan and a revolving term loan of $37.4 million. At September 30, 2012, $15.9 million related to the term loan was outstanding along with the entire revolving term loan. The term loan requires quarterly principal payments of $2.4 million. The term loan matures on August 20, 2014 and the revolving term loan matures on September 1, 2018 with no expected outstanding balances upon maturity on the term loan or the revolving term loan.

 

The Green Plains Ord loan is comprised of a $25.0 million amortizing term loan and a $13.0 million revolving term loan as well as a revolving line of credit of up to $5.0 million. At September 30, 2012, $18.3 million related to the term loan was outstanding, $12.2 million on the revolving term loan, along with $4.3 million on the revolving line of credit. The term loan requires monthly principal payments of approximately $0.2 million. The term loan and the revolving term loan mature on July 1, 2016 with expected outstanding balances upon maturity of $8.2 million and $12.2 million, respectively, and the revolving line of credit matures on June 27, 2013. We expect to extend or refinance the revolving credit facility prior to its maturity.

 

The Green Plains Otter Tail loan is comprised of a $30.3 million amortizing term loan, a $4.7 million revolver and a $19.2 million note payable. At September 30, 2012, $24.0 million related to the term loan, $4.7 million on the revolver and $19.0 million on the note payable were outstanding. The term loan requires monthly principal payments of approximately $0.4 million and the note payable requires monthly principal payments of $0.3 million beginning October 1, 2014. The term loan matures on September 1, 2018 with an expected outstanding balance of $4.8 million and the revolver matures on March 19, 2013. We expect to extend or refinance the revolver on or before its maturity date. 

 

The Green Plains Shenandoah loan is comprised of a $30.0 million amortizing term loan and a $17.0 million revolving term loan. At September 30, 2012, $0.4 million related to the term loan was outstanding along with the entire $17.0 million on the revolving term loan. The term loan requires quarterly principal payments of $1.2 million. The term loan matures on May 20, 2013 and the revolving term loan matures on November 1, 2016 with no expected outstanding balances upon maturity.

 

The Green Plains Superior loan is comprised of a $23.5 million amortizing term loan and a $10.0 million revolving term loan. At September 30, 2012, $16.6 million related to the term loan was outstanding, along with the entire revolving term loan. The term loan requires quarterly principal payments of $1.4 million. The term loan matures on July 20, 2015 and the revolving term loan matures on July 1, 2017 with an expected outstanding balance upon maturity of $1.5 million on the term loan and no expected outstanding balance upon maturity on the revolving term loan.

 

Each term loan, except for the Green Plains Holdings II and Green Plains Otter Tail agreements, has a provision that requires us to make annual special payments equal to a percentage ranging from 65% to 75% of the available free cash flow from the related entity’s operations (as defined in the respective loan agreements), subject to certain limitations. With certain exceptions, the revolving term loans within this segment are generally available for advances throughout the life of the commitment with interest-only payments due each month until the final maturity date.

 

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The term loans and revolving term loans bear interest at LIBOR plus 3.00% to 4.50% or lender-established prime rates. Some have established a floor on the underlying LIBOR index. In some cases, the lender may allow us to elect to pay interest at a fixed interest rate to be determined. As security for the loans, the lenders received a first-position lien on all personal property and real estate owned by the respective entity borrowing the funds, including an assignment of all contracts and rights pertinent to construction and on-going operations of the plant. Additionally, debt facilities of Green Plains Central City and Green Plains Ord are cross-collateralized. These borrowing entities are also required to maintain certain combined financial and non-financial covenants during the terms of the loans.

 

Green Plains Bluffton also received $22.0 million in Subordinate Solid Waste Disposal Facility Revenue Bond funds from the city of Bluffton, Indiana, of which $17.5 million remained outstanding at September 30, 2012. The revenue bond requires: semi-annual principal and interest payments of approximately $1.5 million through March 1, 2019; and a final principal and interest payment of $3.745 million on September 1, 2019. The revenue bond bears interest at 7.50% per annum.

 

Agribusiness Segment

 

The Green Plains Grain loans are comprised of a $30.0 million amortizing term loan and a $195.0 million revolving credit facility with various lenders. The term loan and revolving credit facility mature on November 1, 2021 and October 28, 2013, respectively. Equal payments of principal sufficient to amortize the term loan in full over a 15-year period, plus interest, are due on the first day of every month with the remaining outstanding balance and all accrued interest due on the loan maturity date. The term loan bears interest at a fixed rate of 6.0% per annum. Advances of the revolving credit facility are subject to interest charges at a rate per annum equal to the LIBOR rate for the outstanding period, or the base rate, plus the respective applicable margin. At September 30, 2012, $28.3 million on the term loan and $69.0 million on the revolving loan were outstanding. As security for the term loan the lender received a first priority lien on certain real estate and other property owned by the subsidiaries within the agribusiness segment. As security for the revolving credit facility, the lender received a first priority lien on certain cash, inventory, machinery, accounts receivable and other assets owned by subsidiaries of the agribusiness segment.

 

We have entered into short-term inventory financing agreements with a financial institution. At September 30, 2012, 1.9 million bushels of wheat had been designated as collateral under these agreements at an initial value of $15.1 million. We have accounted for the agreements as short-term notes, rather than sales, and have recorded our repurchase obligation at fair value at the end of each period. At September 30, 2012, the grain inventory and short-term notes payable were valued at $16.2 million.

 

On October 26, 2012, we entered into an asset purchase agreement to sell approximately 32.6 million bushels, or 83%, of our reported agribusiness grain storage capacity and all of our agronomy and retail petroleum operations. Outstanding debt is expected to be reduced by more than $113 million upon closing of this transaction.

 

Marketing and Distribution Segment

 

The Green Plains Trade loan is comprised of a senior secured revolving credit facility of up to $70.0 million, subject to a borrowing base of 85% of eligible receivables. At September 30, 2012, $43.9 million was outstanding on the revolving credit facility. The revolving credit facility expires on March 31, 2014 and bears interest at the lender’s commercial floating rate plus 2.5% or LIBOR plus 3.5%. As security for the loan, the lender received a first-position lien on accounts receivable, inventory and other collateral owned by Green Plains Trade.

 

Corporate Activities

 

            We also have $90.0 million of 5.75% Convertible Senior Notes due 2015. The Notes represent senior, unsecured obligations, with interest payable on May 1 and November 1 of each year. The Notes may be converted into shares of common stock and cash in lieu of fractional shares of the common stock based on a conversion rate initially equal to 69.7788 shares of the common stock per $1,000 principal amount of Notes, which is equal to an initial conversion price of $14.33 per share. The conversion rate is subject to adjustment upon the occurrence of specified events. We may redeem for cash all, but not less than all, of the Notes at any time on and after November 1, 2013, if the last reported sale price of our common stock equals or exceeds 140% of the applicable conversion price for a specified time period, at a redemption price equal to 100% of the principal amount of the Notes, plus accrued and unpaid interest. Default with respect to any loan in excess of $10.0 million constitutes an event of default under the convertible senior notes, which could result in the convertible senior notes being declared due and payable.

 

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In conjunction with the repurchase of common stock on March 9, 2012, the Company signed a one-year promissory note bearing 5% interest per annum in the amount of $27.2 million with a subsidiary of NTR plc. The $27.2 million note is secured by the shares repurchased and the Company’s interest in Green Plains Shenandoah LLC.

 

Contractual Obligations

 

Our contractual obligations as of September 30, 2012 were as follows (in thousands):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Payments Due By Period

Contractual Obligations

 

Total

 

Less than 1 year

 

1-3 years

 

3-5 years

 

More than 5 years

Long-term and short-term debt obligations (1)

 

$       688,997 

 

$       231,006 

 

$       135,144 

 

$       212,959 

 

$       109,888 

Interest and fees on debt obligations (2)

 

91,918 

 

29,274 

 

38,044 

 

17,361 

 

7,239 

Operating lease obligations (3)

 

60,351 

 

19,262 

 

24,534 

 

13,637 

 

2,918 

Deferred tax liabilities

 

64,913 

 

 -

 

 -

 

 -

 

64,913 

Purchase obligations

 

 

 

 

 

 

 

 

 

 

Forward grain purchase contracts (4)

 

457,543 

 

456,337 

 

1,206 

 

 -

 

 -

Other commodity purchase contracts (5)

 

33,180 

 

33,180 

 

 -

 

 -

 

 -

Other

 

13,268 

 

13,136 

 

132 

 

 -

 

 -

Total contractual obligations

 

$    1,410,170 

 

$       782,195 

 

$       199,060 

 

$       243,957 

 

$       184,958 

 

 

 

 

 

 

 

 

 

 

 

(1)Includes the current portion of long-term debt and excludes the discount on long-term debt of $195 thousand.

(2)Interest amounts are calculated over the terms of the loans using current interest rates, assuming scheduled principle and interest amounts are

paid pursuant to the debt agreements.  Includes administrative and/or commitment fees on debt obligations.

(3)Operating lease costs are primarily for railcars and office space.

(4)Purchase contracts represent index-priced and fixed-price contracts. Index purchase contracts are valued at current quarter-end prices.

(5)Includes fixed-price ethanol, dried distillers grains and natural gas purchase contracts.

 

 

 

 

Item 3.  Quantitative and Qualitative Disclosures About Market Risk.

 

We are exposed to various market risks, including changes in commodity prices and interest rates. Market risk is the potential loss arising from adverse changes in market rates and prices. In the ordinary course of business, we enter into various types of transactions involving financial instruments to manage and reduce the impact of changes in commodity prices and interest rates. At this time, we do not expect to have exposure to foreign currency risk as we expect to conduct all of our business in U.S. dollars.

 

Interest Rate Risk

 

We are exposed to market risk from changes in interest rates. Exposure to interest rate risk results primarily from holding term and revolving loans that bear variable interest rates. Specifically, we had $689.0 million outstanding in debt as of September 30, 2012, $492.6 million of which is variable-rate in nature. Interest rates on our variable-rate debt are determined based upon the market interest rate of either the lender’s prime rate or LIBOR, as applicable. A 10% change in interest rates would affect our interest cost on such debt by approximately $2.0 million per year in the aggregate. Other details of our outstanding debt are discussed in the notes to the consolidated financial statements included as a part of this report.

 

Commodity Price Risk

 

We produce ethanol, distillers grains and corn oil from corn and our business is sensitive to changes in the prices of each of these commodities. The price of corn is subject to fluctuations due to unpredictable factors such as weather; corn planted and harvested acreage; changes in national and global supply and demand; and government programs and policies. We use natural gas in the ethanol production process and, as a result, our business is also sensitive to changes in the price of natural gas. The price of natural gas is influenced by such weather factors as extreme heat or cold in the summer and winter, or other natural events like hurricanes in the spring, summer and fall. Other natural gas price factors include North American exploration and production, and the amount of natural gas in underground storage during both the injection and withdrawal seasons. Ethanol prices are sensitive to world crude-oil supply and demand; crude-oil refining capacity and utilization; government regulation; and consumer demand for alternative fuels. Distillers grains prices are sensitive to various demand factors such as numbers of livestock on feed, prices for feed alternatives, and supply factors, primarily production by ethanol plants and other sources.

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We attempt to reduce the market risk associated with fluctuations in the price of corn, natural gas, ethanol, distillers grains and corn oil by employing a variety of risk management and economic hedging strategies. Strategies include the use of forward fixed-price physical contracts and derivative financial instruments, such as futures and options executed on the Chicago Board of Trade and the New York Mercantile Exchange.

 

We focus on locking in operating margins based on a model that continually monitors market prices of corn, natural gas and other input costs against prices for ethanol and distillers grains at each of our production facilities. We create offsetting positions by using a combination of forward fixed-price physical purchases and sales contracts and derivative financial instruments. As a result of this approach, we frequently have gains on derivative financial instruments that are conversely offset by losses on forward fixed-price physical contracts or inventories and vice versa. In our ethanol production segment, gains and losses on derivative financial instruments are recognized each period in operating results, unless designated as cash flow hedges, while corresponding gains and losses on physical contracts are generally designated as normal purchases or normal sales contracts and are not recognized until quantities are delivered or utilized in production. For cash flow hedges, any ineffectiveness is recognized in current period results, while other unrealized gains and losses are deferred in accumulated other comprehensive income until gains and losses from the underlying hedged transaction are realized. In the event that it becomes probable that a forecasted transaction will not occur, we would discontinue cash flow hedge treatment, which would affect earnings. During the nine months ended September 30, 2012, revenues and cost of goods sold included net losses of $9.9 million and $2.7 million from derivative financial instruments, respectively. To the extent net gains or losses from settled derivative instruments are related to hedging current period production, they are generally offset by physical commodity purchases or sales resulting in the realization of the intended operating margins. However, our results of operations are impacted when there is a mismatch of gains or losses associated with the change in fair value of derivative instruments at the reporting period when the physical commodity purchase or sales has not yet occurred since they are designated as a normal purchase or normal sale.

 

In our agribusiness segment, inventory positions, physical purchase and sale contracts, and financial derivatives are marked to market with gains and losses included in results of operations.  The market value of derivative financial instruments such as exchange-traded futures and options has a high, but not perfect, correlation to the underlying market value of grain inventories and related purchase and sale contracts.

 

Ethanol Production Segment

 

A sensitivity analysis has been prepared to estimate our ethanol production segment exposure to ethanol, corn, distillers grains and natural gas price risk. Market risk related to these factors is estimated as the potential change in net income resulting from hypothetical 10% changes in prices of our expected corn and natural gas requirements, and ethanol and distillers grains output for a one-year period from September 30, 2012. This analysis includes the impact of risk management activities that result from our use of fixed-price purchase and sale contracts and derivatives. The results of this analysis, which may differ from actual results, are as follows (in thousands):

 

 

 

 

 

 

 

 

 

Commodity

 

Estimated Total Volume Requirements for the Next 12 Months

 

Unit of Measure

 

Net Income Effect of Approximate 10% Change
in Price

 Ethanol

 

740,000

 

Gallons

 

$

96,761

 Corn

 

265,000

 

Bushels

 

$

106,297

 Distillers grains

 

2,100

 

Tons (1)

 

$

28,498

 Natural gas

 

20,300

 

MMBTU (2)

 

$

4,562

 

 

 

 

 

 

 

 

(1) Distillers grains quantities are stated on an equivalent dried ton basis.

 

 

(2) Millions of British Thermal Units

 

 

 

 

 

 

 

Corn Oil Production Segment

 

A sensitivity analysis has been prepared to estimate our corn oil production segment exposure to corn oil price risk. Market risk related to these factors is estimated as the potential change in net income resulting from hypothetical 10% changes in prices of our expected corn oil output for a one-year period from September 30, 2012. This analysis includes the impact of risk management activities that result from our use of fixed-price sale contracts. Market risk at September 30, 2012, based on the estimated net income effect resulting from a hypothetical 10% change in such prices, was approximately $0.5 million.

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Agribusiness Segment

 

The availability and price of agricultural commodities are subject to wide fluctuations due to unpredictable factors such as weather, plantings, foreign and domestic government farm programs and policies, changes in global demand created by population changes and changes in standards of living, and global production of similar and competitive crops. To reduce price risk caused by market fluctuations in purchase and sale commitments for grain and grain held in inventory, we enter into exchange-traded futures and options contracts that function as economic hedges. The market value of exchange-traded futures and options used for economic hedging has a high, but not perfect correlation, to the underlying market value of grain inventories and related purchase and sale contracts. The less correlated portion of inventory and purchase and sale contract market value, known as basis, is much less volatile than the overall market value of exchange-traded futures and tends to follow historical patterns. We manage this less volatile risk by constantly monitoring our position relative to the price changes in the market. In addition, inventory values are affected by the month-to-month spread relationships in the regulated futures markets, as we carry inventories over time. These spread relationships are also less volatile than the overall market value and tend to follow historical patterns, but also represent a risk that cannot be directly offset. Our accounting policy for our futures and options, as well as the underlying inventory positions and purchase and sale contracts, is to mark them to the market and include gains and losses in the consolidated statement of operations in sales and merchandising revenues.

 

A sensitivity analysis has been prepared to estimate agribusiness segment exposure to market risk of our commodity position (exclusive of basis risk). Our daily net commodity position consists of inventories related to purchase and sale contracts and exchange-traded contracts. The fair value of our position, which is a summation of the fair values calculated for each commodity by valuing each net position at quoted futures market prices, is approximately $131.6 thousand at September 30, 2012. Market risk at that date, based on the estimated net income effect resulting from a hypothetical 10% change in such prices, was approximately $8 thousand.

 

Item 4.  Controls and Procedures.

 

Evaluation of Disclosure Controls and Procedures

 

We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in the reports that we file or submit under the Securities Exchange Act of 1934, or Exchange Act, is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required financial disclosure.

 

As of the end of the period covered by this report, our management carried out an evaluation, under the supervision of and with the participation of our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act). Our disclosure controls and procedures are designed to ensure that information required to be disclosed in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms. These disclosure controls and procedures are designed to ensure that information required to be disclosed by us in the reports that it files or submits under the Exchange Act is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required financial disclosure. Based upon that evaluation, our management, including our Chief Executive Officer and the Chief Financial Officer, concluded that our disclosure controls and procedures were effective.

 

Changes in Internal Control over Financial Reporting

 

Our management is responsible for establishing and maintaining effective internal control over financial reporting to provide reasonable assurance regarding the reliability of our financial reporting and the preparation of our consolidated financial statements for external purposes in accordance with generally accepted accounting principles. There were no material changes in our internal control over financial reporting that occurred during the period covered by this quarterly report that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

 

 

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PART II – OTHER INFORMATION

 

Item 1.  Legal Proceedings.

 

We are currently involved in litigation that has arisen in the ordinary course of business; however, we do not believe that any of this litigation will have a material adverse effect on our financial position, results of operations or cash flows.

 

Item 1A.  Risk Factors.

 

Our investors should consider the risks that could affect us and our business as set forth in Part I, Item 1A, “Risk Factors” of our annual report on Form 10-K for the year ended December 31, 2011. Although we have attempted to discuss key factors, our investors need to be aware that other risks may prove to be important in the future. New risks may emerge at any time and we cannot predict such risks or estimate the extent to which they may affect our financial performance. Investors should also consider the discussion of risks and the other information included in this quarterly report on Form 10-Q, including Cautionary Information Regarding Forward-Looking Information, which is included in Part I, Item 2, “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”

 

The following risk factors, which modifies risk factors set forth in our annual report on Form 10-K for the year ended December 31, 2011, to include information related to potential price volatility of crude oil and an update regarding regulation of greenhouse gasses, should be considered in conjunction with the other information included in, or incorporated by reference in, this quarterly report on Form 10-Q.

 

Price volatility of each commodity that we buy and sell could each adversely affect our results of operations and our ability to operate at a profit.

 

Corn.  Because ethanol competes with non-corn derived fuels, we generally are unable to pass along increases in corn costs to our customers. At certain levels, corn prices may make ethanol uneconomical to produce. There is significant price pressure on local corn markets caused by nearby ethanol plants, livestock industries and other corn consuming enterprises. Additionally, local corn supplies and prices could be adversely affected by rising prices for alternative crops, increasing input costs, changes in government policies, shifts in global markets, or damaging growing conditions such as plant disease or adverse weather, including but not limited to drought.

 

Natural Gas.  The prices for and availability of natural gas are subject to volatile market conditions. These market conditions often are affected by factors beyond our control, such as weather conditions, 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. Furthermore, increases in natural gas prices or changes in our natural gas costs relative to natural gas costs paid by competitors may adversely affect our results of operations and financial position.

 

Ethanol.  Our revenues are dependent on market prices for ethanol. These market prices can be volatile as a result of a number of factors, including, but not limited to, the availability and price of competing fuels, the overall supply and demand for ethanol and corn, the price of gasoline and corn, and the level of government support.

 

Ethanol is marketed as a fuel additive to reduce vehicle emissions from gasoline, as an octane enhancer to improve the octane rating of the gasoline with which it is blended and, to a lesser extent, as a gasoline substitute. As a result, ethanol prices are influenced by the supply of and demand for gasoline. Our results of operations may be materially harmed if the demand for, or the price of, gasoline decreases. Conversely, a prolonged increase in the price of, or demand for, gasoline could lead the U.S. government to avoid limiting imported ethanol; the import tariff of $0.54 per gallon was allowed to expire on December 31, 2011.

 

Distillers Grains.  Distillers grains compete with other protein-based animal feed products. The price of distillers grains may decrease when the prices of competing feed products decrease. The prices of competing animal feed products are based in part on the prices of the commodities from which these products 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.

 

Historically, sales prices for distillers grains have been correlated with prices of corn. However, there have been occasions when the price increase for this co-product has lagged behind increases in corn prices. In addition, our distillers grains co-product competes with products made from other feedstocks, the cost of which may not have risen as corn prices

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have risen. Consequently, the price we may receive for distillers grains may not rise as corn prices rise, thereby lowering our cost recovery percentage relative to corn.

 

Due to industry increases in U.S. dry mill ethanol production, the production of distillers grains in the United States has increased dramatically, and this trend may continue. This may cause distillers grains prices to fall in the United States, unless demand increases or other market sources are found. To date, demand for distillers grains in the United States has increased roughly in proportion to supply. We believe this is because U.S. farmers use distillers grains as a feedstock, and distillers grains are slightly less expensive than corn, for which it is a substitute. However, if prices for distillers grains in the U.S. fall, it may have an adverse effect on our business.

 

Corn Oil.  Industrial uses for corn oil include feedstock for biodiesel, livestock feed additives, rubber substitutes, rust preventatives, inks, textiles, soaps and insecticides. Corn oil is generally marketed as a feedstock for biodiesel and, therefore, the price of corn oil is affected by demand for biodiesel. In general, corn oil prices follow the same price trends as heating oil and soybean oil. If prices for corn oil fluctuate, it may have an adverse effect on our business.

 

Crude Oil. In addition to the commodities that we produce, buy and sell related to ethanol production, we buy and sell crude oil to optimize the utilization of our railcar fleet. Crude oil revenues historically have not been significant to our business; however, our business may be materially affected by price volatility of crude oil in the future as we may increase the volume of our crude oil transactions.

 

The ethanol industry is highly dependent on government usage mandates affecting ethanol production and favorable tax benefits for ethanol blending and any changes to such regulation could adversely affect the market for ethanol and our results of operations.

 

The domestic market for ethanol is largely dictated by federal mandates for blending ethanol with gasoline. The RFS II mandate level for conventional biofuels for 2012 of 13.2 billion gallons approximates current domestic production levels. Future demand will be largely dependent upon the economic incentives to blend based upon the relative value of gasoline versus ethanol, taking into consideration the relative octane value of ethanol, environmental requirements and the RFS II mandate. Any significant increase in production capacity beyond the RFS II mandated level might have an adverse impact on ethanol prices.

 

Additionally, under the provisions of the Energy Independence and Security Act, the EPA has the authority to waive the mandated RFS II requirements in whole or in part. To grant the waiver, the EPA administrator must determine, in consultation with the Secretaries of Agriculture and Energy, that one of two conditions has been met; there is inadequate domestic renewable fuel supply or implementation of the requirement would severely harm the economy or environment of a state, a region or the U.S. In the third quarter of 2012, the governors of North Carolina and Arkansas as well as a number of livestock groups filed waiver requests with the EPA based on drought conditions. On August 20, 2012 the EPA asked for public comment on the need for an ethanol waiver. The agency has until November 13, 2012 to make a decision regarding the potential waiver. Our operations could be adversely impacted if a waiver is granted.

 

The RFS Flexibility Act was introduced on October 5, 2011 in the U.S. House of Representatives to reduce or eliminate the volumes of renewable fuel use required by the RFS II mandate based upon corn stocks-to-use ratios. The Domestic Alternative Fuels Act of 2012 was introduced on January 18, 2012 in the U.S. House of Representatives to modify the RFS II mandate to include ethanol and other fuels produced from fossil fuels like coal and natural gas. Due to current drought conditions, the possibility of further legislation aimed at reducing or eliminating the renewable fuel use required by the RFS II mandate may also be heightened. We believe the RFS II mandate is a significant component of national energy policy that reduces dependence on foreign oil by the United States. Our operations could be adversely impacted if the RFS Flexibility Act or the Domestic Alternative Fuels Act of 2012 are enacted.

 

Referred to as the blender’s credit, the Volumetric Ethanol Excise Tax Credit, or VEETC, provided companies with a tax credit to blend ethanol with gasoline. The Food, Conservation and Energy Act of 2008, or the 2008 Farm Bill, amended the amount of tax credit provided under VEETC to 45 cents per gallon of pure ethanol and 38 cents per gallon for E85, a blended motor fuel containing 85% ethanol and 15% gasoline. The blender’s credit expired on December 31, 2011.

 

Federal law mandates the use of oxygenated gasoline. If these mandates are repealed, the market for domestic ethanol would be diminished significantly. Additionally, flexible-fuel vehicles receive preferential treatment in meeting corporate average fuel economy, or CAFE, standards. However, high blend ethanol fuels such as E85 result in lower fuel efficiencies. Absent the CAFE preferences, it may be unlikely that auto manufacturers would build flexible-fuel vehicles. Any change in these CAFE preferences could reduce the growth of E85 markets and result in lower ethanol prices, which could adversely

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impact our operating results.

 

To the extent that such federal or state laws or regulations are modified, the demand for ethanol may be reduced, which could negatively and materially affect our ability to operate profitably.

 

Our business is affected by the regulation of greenhouse gases, or GHG, and climate change. New climate change regulations could impede our ability to successfully operate our business.

 

Our plants emit carbon dioxide as a by-product of the ethanol production process. In 2007, the U.S. Supreme Court classified carbon dioxide as an air pollutant under the Clean Air Act in a case seeking to require the EPA to regulate carbon dioxide in vehicle emissions. On February 3, 2010, the EPA released its final regulations on RFS II. We believe these final regulations grandfather our plants at their current operating capacity, though expansion of our plants will need to meet a threshold of a 20% reduction in GHG emissions from a 2005 baseline measurement for the ethanol over current capacity to be eligible for the RFS 2 mandate. The EPA issued its final rule on GHG emissions from stationary sources under the Clean Air Act in May 2010. These final rules may require us to apply for additional permits for our ethanol plants. In order to expand capacity at our plants, we may have to apply for additional permits, install advanced technology, or reduce drying of certain amounts of distillers grains. We may also be required to install carbon dioxide mitigation equipment or take other steps unknown to us at this time in order to comply with other future law or regulation. Compliance with future law or regulation of carbon dioxide, or if we choose to expand capacity at certain of our plants, compliance with then-current regulation of carbon dioxide, could be costly and may prevent us from operating our plants as profitably, which may have an adverse impact on our operations, cash flows and financial position.

 

The California Air Resources Board, or CARB, has adopted a Low Carbon Fuel Standard, or LCFS, requiring a 10% reduction in GHG emissions from transportation fuels by 2020. Additionally, an Indirect Land Use Change, or ILUC, component is included in the lifecycle GHG emissions calculation. On December 29, 2011, the U.S. District Court for the Eastern District of California issued several rulings in federal lawsuits challenging the LCFS. One of the rulings preliminarily prevents CARB from enforcing these regulations during the pending litigation. On January 23, 2012, CARB unsuccessfully attempted to appeal these rulings in the U.S. District Court for the Eastern District of California and on January 26, 2012 filed another appeal with the Ninth Circuit Court of Appeals. On April 22, 2012, the Court of Appeals granted the request to put a hold on the December 29, 2011 ruling, which was to have taken effect on January 1, 2012. The decision allows CARB to continue implementation and resume enforcement of the LCFS. While this standard may continue to be challenged, implementation of such a standard may have an adverse impact on our market for corn-based ethanol in California if it is determined that corn-based ethanol fails to achieve lifecycle GHG emission reductions.

 

Depending on commodity prices, foreign producers may produce ethanol at a lower cost than we can, which may result in lower ethanol prices which would adversely affect our financial results.

 

There is a risk of foreign competition in the ethanol industry. Brazil is currently the second largest ethanol producer in the world. Brazil’s ethanol production is sugarcane based, as opposed to corn based, and has historically been less expensive to produce. Under RFS II, certain parties are obligated to meet an advanced biofuel standard calling for 2.0 billion gallons of biofuels in 2012. During 2012, sugarcane ethanol imported from Brazil has been one of the most economical means for obligated parties to meet this standard. Other foreign producers may be able to produce ethanol at lower input costs, including costs of feedstock, facilities and personnel, than we can.

 

While foreign demand, transportation costs and infrastructure constraints may temper the market impact throughout the United States, competition from imported ethanol may affect our ability to sell our ethanol profitably, which may have an adverse effect on our operations, cash flows and financial position.

 

If significant additional foreign ethanol production capacity is created, such facilities could create excess supplies of ethanol on world markets, which may result in lower prices of ethanol throughout the world, including the United States. Such foreign competition is a risk to our business. Any penetration of ethanol imports into the domestic market may have a material adverse effect on our operations, cash flows and financial position.

 

Item 2.  Unregistered Sales of Equity Securities and Use of Proceeds.

 

Employees surrender shares upon the vesting of restricted stock grants to satisfy payroll tax withholding obligations. No restricted stock vested during the third quarter of 2012 and therefore no shares were surrendered. On March 9, 2012, we repurchased 3.7 million shares of common stock for $37.2 million from a subsidiary of NTR plc, which was previously our largest shareholder. We do not have a share repurchase program and do not intend to retire the repurchased shares.

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Item 3.  Defaults Upon Senior Securities.

 

None.

 

Item 4.  Mine Safety Disclosures.

 

Not applicable.

 

Item 5.  Other Information.

 

None. 

 

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Item 6.  Exhibits.

Exhibit Index 

 

 

 

 

 

 

 

Exhibit No.

Description

 

 

2.1

Asset Purchase Agreement among Green Plains Grain Company LLC, Green Plains Grain Company TN LLC, Green Plains Renewable Energy, Inc. and The Andersons, Inc. dated October 26, 2012 (Incorporated by reference to Exhibit 2.1 of the Company’s Form 8-K filed October 29, 2012)

3.1

Second Amended and Restated Bylaws of Green Plains Renewable Energy, Inc., dated August 14, 2012 (Incorporated by reference to Exhibit 3.1 of the Company’s Form 8-K filed August 15, 2012)

10.1

Second Amendment to Amended and Restated Master Loan Agreement, dated September 28, 2012, by and among Green Plains Bluffton LLC and AgStar Financial Services, PCA

10.2

Fourth Amendment dated September 28, 2012 to the Credit Agreement, as amended, dated June 2, 2009, by and among Green Plains Ord LLC, Green Plains Holdings LLC, AgStar Financial Services, PCA as Administrative Agent and the Banks named therein

10.3

Fifth Amendment dated September 28, 2012 to the Credit Agreement, as amended, dated June 2, 2009, by and among Green Plains Central City LLC, Green Plains Holdings LLC, AgStar Financial Services, PCA as Administrative Agent and the Banks named therein

10.4

First Amendment to Amended and Restated Credit Agreement, dated October 16, 2012, by and between Green Plains Holdings II LLC and CoBank, ACB

10.5

Second Amendment to Credit Agreement, dated October 26, 2012, by and among Green Plains Grain Company LLC, Green Plains Grain Company TN LLC, Green Plains Essex, Inc., BNP Paribas, as the administrative agent under the Credit Agreement, and the lenders party to the Credit Agreement

10.6

Amendment to the Master Loan Agreement, dated October 24, 2012, between Farm Credit Services of Mid-America, FLCA, Farm Credit Services of Mid-America, PCA and Green Plains Obion LLC

31.1

Certification of Chief Executive Officer pursuant to Rule 13a-14(a) and Section 302 of the Sarbanes-Oxley Act of 2002

31.2

Certification of Chief Financial Officer pursuant to Rule 13a-14(a) and 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

101

The following information from Green Plains Renewable Energy, Inc.’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2012, formatted in Extensible Business Reporting Language (XBRL): (i) Consolidated Balance Sheets, (ii) Consolidated Statements of Operations, (iii) Consolidated Statements of Comprehensive Income, (iv) Consolidated Statements of Cash Flows, and (v) the Notes to Consolidated Financial Statements

 

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SIGNATURES

 

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

 

 

 

 

 





Date: November 1, 2012

GREEN PLAINS RENEWABLE ENERGY, INC.

(Registrant)

 

 

By:   /s/ Todd A. Becker                                 _    

Todd A. Becker
President and Chief Executive Officer

(Principal Executive Officer)

 




Date: November 1, 2012

 

 

 

By:   /s/ Jerry L. Peters                                   _

Jerry L. Peters
Chief Financial Officer

(Principal Financial Officer)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

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XBRL ONLY

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