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, 2021

Commission File Number 001-32924

Green Plains 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.)
1811 Aksarben Drive, Omaha, NE 68106	(402) 884-8700
(Address of principal executive offices, including zip code)	(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol	Name of each exchange on which registered
Common Stock, par value $0.001 per share	GPRE	The Nasdaq Stock Market LLC

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.

x Yes o No

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted 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 such files).

x Yes o No

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

Large accelerated filer o	Accelerated filer x
Non-accelerated filer o
Smaller reporting company o	Emerging growth company o

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

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

o Yes x No

The number of shares of common stock, par value $0.001 per share, outstanding as of November 1, 2021, was 53,595,978 shares.

TABLE OF CONTENTS

		Page
Commonly Used Defined Terms		2
PART I – FINANCIAL INFORMATION
Item 1.	Financial Statements	3
	Consolidated Balance Sheets	3
	Consolidated Statements of Operations	4
	Consolidated Statements of Comprehensive Income	5
	Consolidated Statements of Cash Flows	6
	Notes to Consolidated Financial Statements	8
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	35
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	52
Item 4.	Controls and Procedures	54
PART II – OTHER INFORMATION
Item 1.	Legal Proceedings	55
Item 1A.	Risk Factors	55
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	58
Item 3.	Defaults Upon Senior Securities	58
Item 4.	Mine Safety Disclosures	58
Item 5.	Other Information	58
Item 6.	Exhibits	59
Signatures		60

1

Commonly Used Defined Terms

Green Plains Inc. and Subsidiaries:

Green Plains; the company	Green Plains Inc. and its subsidiaries
BioProcess Algae	BioProcess Algae LLC
FQT	Fluid Quip Technologies, LLC
Green Plains Cattle; GPCC	Green Plains Cattle Company LLC
Green Plains Commodity Management	Green Plains Commodity Management LLC
Green Plains Grain	Green Plains Grain Company LLC
Green Plains Mount Vernon; Mount Vernon	Green Plains Mount Vernon LLC
Green Plains Obion; Obion	Green Plains Obion LLC
Green Plains Partners; the partnership	Green Plains Partners LP
Green Plains Shenandoah; Shenandoah	Green Plains Shenandoah LLC
Green Plains Trade	Green Plains Trade Group LLC
Green Plains Wood River; Wood River	Green Plains Wood River LLC

Accounting Defined Terms:

ASC	Accounting Standards Codification
EBITDA	Earnings before interest, income taxes, depreciation and amortization
EPS	Earnings per share
Exchange Act	Securities Exchange Act of 1934, as amended
GAAP	U.S. Generally Accepted Accounting Principles
JV	Joint Venture
LIBOR	London Interbank Offered Rate
SEC	Securities and Exchange Commission

Industry and Other Defined Terms:

BlackRock	Funds and accounts managed by BlackRock
CAFE	Corporate Average Fuel Economy
CARB	California Air Resources Board
the CARES Act	Coronavirus Aid, Relief, and Economic Security Act
COVID-19	Coronavirus Disease 2019
CST	Clean Sugar Technology
DOE	Department of Energy
E10	Gasoline blended with up to 10% ethanol by volume
E15	Gasoline blended with up to 15% ethanol by volume
E85	Gasoline blended with up to 85% ethanol by volume
EIA	U.S. Energy Information Administration
EPA	U.S. Environmental Protection Agency
FFV	Flexible-fuel vehicle
GNS	Grain Neutral Spirits
MmBtu	Million British Thermal Units
Mmg	Million gallons
MTBE	Methyl tertiary-butyl ether
MVC	Minimum volume commitment
RFS II	Renewable Fuels Standard II
RIN	Renewable identification number
RVO	Renewable volume obligation
SRE	Small refinery exemption
U.S.	United States
USDA	U.S. Department of Agriculture

‎

2

PART 1 – FINANCIAL INFORMATION

Item 1. Financial Statements.

GREEN PLAINS INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(in thousands, except share amounts)

	September 30, ‎2021		December 31, ‎2020
	(unaudited)
ASSETS
Current assets
Cash and cash equivalents	$	589,822	$	233,860
Restricted cash		131,073		40,950
Accounts receivable, net of allowances of $382 and $143, respectively		90,271		55,568
Income taxes receivable		1,732		661
Inventories		243,207		269,491
Prepaid expenses and other		15,730		16,531
Derivative financial instruments		45,691		25,292
Total current assets		1,117,526		642,353
Property and equipment, net of accumulated depreciation ‎and amortization of $547,599 and $530,194, respectively		842,141		801,690
Operating lease right-of-use assets		66,971		61,883
Other assets		86,566		72,991
Total assets	$	2,113,204	$	1,578,917
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities
Accounts payable	$	112,459	$	140,058
Accrued and other liabilities		42,731		38,471
Derivative financial instruments		35,401		20,265
Operating lease current liabilities		16,766		14,902
Short-term notes payable and other borrowings		162,470		140,808
Current maturities of long-term debt		34,477		98,052
Total current liabilities		404,304		452,556
Long-term debt		514,434		287,299
Operating lease long-term liabilities		53,050		49,549
Other liabilities		23,798		12,849
Total liabilities		995,586		802,253
Commitments and contingencies (Note 13)
Stockholders' equity
Common stock, $0.001 par value; 75,000,000 shares authorized; ‎61,838,598 and 47,470,505 shares issued, and 53,594,142 ‎and 35,657,344 shares outstanding, respectively		65		47
Additional paid-in capital		1,067,583		740,889
Retained earnings (deficit)		(5,631)		39,375
Accumulated other comprehensive income (loss)		1,038		(2,172)
Treasury stock, 8,244,456 and 11,813,161 shares, respectively		(91,626)		(131,287)
Total Green Plains stockholders' equity		971,429		646,852
Noncontrolling interests		146,189		129,812
Total stockholders' equity		1,117,618		776,664
Total liabilities and stockholders' equity	$	2,113,204	$	1,578,917

See accompanying notes to the consolidated financial statements.
‎

3

GREEN PLAINS 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,
	2021		2020		2021		2020
Revenues
Product revenues	$	745,240	$	423,027	$	2,019,006	$	1,441,248
Service revenues		1,551		1,035		5,843		3,707
Total revenues		746,791		424,062		2,024,849		1,444,955
Costs and expenses
Cost of goods sold (excluding depreciation and amortization expenses reflected below)		730,179		393,933		1,878,820		1,372,057
Operations and maintenance expenses		5,162		6,647		17,153		19,410
Selling, general and administrative expenses		26,022		19,934		72,923		62,090
Loss (gain) on sale of assets, net		1,823		(2,000)		(31,245)		(2,000)
Goodwill impairment		-		-		-		24,091
Depreciation and amortization expenses		28,280		19,753		69,493		57,208
Total costs and expenses		791,466		438,267		2,007,144		1,532,856
Operating income (loss)		(44,675)		(14,205)		17,705		(87,901)
Other income (expense)
Interest income		25		3		496		643
Interest expense		(9,488)		(10,169)		(60,225)		(29,536)
Other, net		(440)		12		(1,680)		862
Total other expense		(9,903)		(10,154)		(61,409)		(28,031)
Loss before income taxes and income from equity method investees		(54,578)		(24,359)		(43,704)		(115,932)
Income tax benefit (expense)		(7)		(7,280)		2,914		48,461
Income from equity method investees, net of income taxes		174		906		517		20,917
Net loss		(54,411)		(30,733)		(40,273)		(46,554)
Net income attributable to noncontrolling interests		5,211		3,753		16,151		12,591
Net loss attributable to Green Plains	$	(59,622)	$	(34,486)	$	(56,424)	$	(59,145)
Earnings per share:
Net loss attributable to Green Plains - basic and diluted	$	(1.18)	$	(1.00)	$	(1.27)	$	(1.71)
Weighted average shares outstanding:
Basic and diluted		50,482		34,629		44,581		34,632

See accompanying notes to the consolidated financial statements.

‎

4

GREEN PLAINS INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(unaudited and in thousands)

	Three Months Ended ‎September 30,				Nine Months Ended ‎September 30,
	2021		2020		2021		2020
Net loss	$	(54,411)	$	(30,733)	$	(40,273)	$	(46,554)
Other comprehensive income (loss), net of tax:
Unrealized gains (losses) on derivatives arising during the period, net of tax benefit (expense) of ($171), $859, ($260) and ($160), respectively		538		(2,696)		820		503
Reclassification of realized losses (gains) on derivatives, net of tax benefit (expense) of $62, $0, ($750) and $1,431, respectively		(194)		-		2,390		(4,492)
Other comprehensive income (loss), net of tax		344		(2,696)		3,210		(3,989)
Share of equity method investees other comprehensive income (loss) arising during the period, net of tax benefit (expense) of $0, $6,705, $0 and ($1,318), respectively		-		(21,057)		-		4,140
Total other comprehensive income (loss), net of tax		344		(23,753)		3,210		151
Comprehensive loss		(54,067)		(54,486)		(37,063)		(46,403)
Comprehensive income attributable to noncontrolling interests		5,211		3,753		16,151		12,591
Comprehensive loss attributable to Green Plains	$	(59,278)	$	(58,239)	$	(53,214)	$	(58,994)

See accompanying notes to the consolidated financial statements.

‎

5

GREEN PLAINS INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited and in thousands)

	Nine Months Ended ‎September 30,
	2021		2020
Cash flows from operating activities:
Net loss	$	(40,273)	$	(46,554)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Depreciation and amortization		69,493		57,208
Amortization of debt issuance costs and debt discount		6,957		16,097
Gain on sale of assets, net		(31,245)		(1,405)
Loss on extinguishment of debt		32,645		-
Goodwill impairment		-		24,091
Deferred income taxes		(3,008)		(10,569)
Stock-based compensation		3,980		5,720
Income from equity method investees, net of income taxes		(517)		(20,917)
Distribution from equity method investees, net of income taxes		-		27,910
Other		1,199		18
Changes in operating assets and liabilities before effects of business combinations and dispositions:
Accounts receivable		(33,776)		54,683
Inventories		4,088		68,301
Derivative financial instruments		(2,386)		5,532
Prepaid expenses and other assets		175		2,051
Accounts payable and accrued liabilities		(35,007)		(78,091)
Current income taxes		(1,073)		(26,825)
Other		876		(802)
Net cash provided by (used in) operating activities		(27,872)		76,448
Cash flows from investing activities:
Purchases of property and equipment, net		(123,687)		(85,376)
Proceeds from the sale of assets		87,217		-
Other investing activities		(7,000)		(4,098)
Net cash used in investing activities		(43,470)		(89,474)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		367,701		13,000
Payments of principal on long-term debt		(188,706)		(12,933)
Proceeds from short-term borrowings		2,450,416		1,816,821
Payments on short-term borrowings		(2,432,553)		(1,866,526)
Payments on extinguishment of convertible debt		(20,861)		-
Payments for repurchase of common stock		-		(11,479)
Payments of cash distributions		(4,187)		(8,281)
Proceeds from issuance of common stock, net		356,011		-
Payments of loan fees		(9,050)		(3,900)
Payments related to tax withholdings for stock-based compensation		(4,674)		(1,288)
Other financing activities		3,330		-
Net cash provided by (used in) financing activities		517,427		(74,586)
Net change in cash, cash equivalents and restricted cash		446,085		(87,612)
Cash, cash equivalents and restricted cash, beginning of period		274,810		269,896
Cash, cash equivalents and restricted cash, end of period	$	720,895	$	182,284
Continued on the following page

6

GREEN PLAINS INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited and in thousands)

Continued from the previous page
	Nine Months Ended ‎September 30,
	2021		2020
Reconciliation of total cash, cash equivalents and restricted cash:
Cash and cash equivalents	$	589,822	$	150,407
Restricted cash		131,073		31,877
Total cash, cash equivalents and restricted cash	$	720,895	$	182,284
Non-cash financing activity:
Exchange of 4.00% convertible notes due 2024	$	51,000	$	-
Exchange of common stock held in treasury stock for 4.00% ‎convertible notes due 2024	$	39,661	$	-
Supplemental investing activities:
Assets disposed of in sale	$	54,626	$	-
Less: liabilities relinquished		(3,706)		-
Net assets disposed	$	50,920	$	-
Supplemental disclosures of cash flow:
Cash paid (refunded) for income taxes, net	$	1,336	$	(4,533)
Cash paid for interest	$	25,529	$	20,325
Cash premium paid for extinguishment of convertible notes	$	20,861	$	-

See accompanying notes to the consolidated financial statements.

‎

7

GREEN PLAINS 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 Inc., an Iowa corporation, and its subsidiaries.

Consolidated Financial Statements

The consolidated financial statements include the company’s accounts and all significant intercompany balances and transactions are eliminated. Unconsolidated entities are included in the financial statements on an equity basis. The company owns a 48.9% limited partner interest and a 2.0% general partner interest in Green Plains Partners LP. Public investors own the remaining 49.1% limited partner interest in the partnership. The company determined that the limited partners in the partnership with equity at risk lack the power, through voting rights or similar rights, to direct the activities that most significantly impact the partnership’s economic performance; therefore, the partnership is considered a variable interest entity. The company, through its ownership of the general partner interest in the partnership, has the power to direct the activities that most significantly affect economic performance and is obligated to absorb losses and has the right to receive benefits that could be significant to the partnership. Therefore, the company is considered the primary beneficiary and consolidates the partnership in the company’s financial statements. The assets of the partnership cannot be used by the company for general corporate purposes. The partnership’s consolidated total assets as of September 30, 2021 and December 31, 2020, excluding intercompany balances, are $102.1 million and $91.2 million, respectively, and primarily consist of property and equipment, operating lease right-of-use assets and goodwill. The partnership’s consolidated total liabilities as of September 30, 2021 and December 31, 2020, excluding intercompany balances, are $112.6 million and $151.2 million, respectively, which primarily consist of long-term debt as discussed in Note 8 – Debt and operating lease liabilities. The liabilities recognized as a result of consolidating the partnership do not represent additional claims on our general assets.

The company also owns a majority interest in BioProcess Algae, a joint venture formed in 2008, as well as a majority interest in Fluid Quip Technologies, LLC, with their results being consolidated in our consolidated financial statements.

The accompanying unaudited consolidated financial statements are prepared in accordance with GAAP for interim financial information and the instructions to Form 10-Q and Article 10 of Regulation S-X. Because they do not include all of the information and notes required by GAAP, the consolidated financial statements should be read in conjunction with the company’s annual report on Form 10-K for the year ended December 31, 2020, filed with the SEC on February 16, 2021.

The unaudited financial information reflects adjustments, which are, in the opinion of management, necessary for a fair presentation of results of operations, financial position and cash flows for the periods presented. The adjustments are normal and recurring in nature, unless otherwise noted. Interim period results are not necessarily indicative of the results to be expected for the entire year.

Reclassifications

Certain prior year amounts have been reclassified to conform to the current year presentation. These reclassifications did not affect total revenues, costs and expenses or net income. See Note 8 – Debt and Note 11 – Stockholders’ Equity for further details.

8

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, 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. The company bases its estimates on historical experience and assumptions it believes are proper and reasonable under the circumstances and regularly evaluates the appropriateness of its estimates and assumptions. Actual results could differ from those estimates. Key accounting policies, including but not limited to those relating to revenue recognition, carrying value of intangible assets, operating leases, impairment of long-lived assets and goodwill, derivative financial instruments, accounting for income taxes and assets acquired and liabilities assumed in acquisitions, are impacted significantly by judgments, assumptions and estimates used in the preparation of the consolidated financial statements.

Description of Business

The company operates within four business segments: (1) ethanol production, which includes the production of ethanol, including industrial-grade alcohol, distillers grains, Ultra-High Protein and corn oil, (2) agribusiness and energy services, which includes grain handling and storage, commodity marketing and merchant trading for company-produced and third-party ethanol, distillers grains, corn oil, natural gas and other commodities, (3) food and ingredients, which includes food-grade corn oil and (4) partnership, which includes fuel storage and transportation services. The food and ingredients segment had no activity during the three and nine months ended September 30, 2021 and 2020.

Cash and Cash Equivalents

Cash and cash equivalents includes bank deposits as well as short-term, highly liquid investments with original maturities of three months or less.

Restricted Cash

The company has restricted cash, which can only be used for funding letters of credit, for payment towards a revolving credit agreement, or for capital expenditures as specified in certain credit facility agreements. Restricted cash also includes cash margins and securities pledged to commodity exchange clearinghouses and at times, funds in escrow related to acquisition and disposition activities. To the degree these segregated balances are cash and cash equivalents, they are considered restricted cash on the consolidated balance sheets.

Revenue Recognition

The company recognizes revenue when obligations under the terms of a contract with a customer are satisfied. Generally, this occurs with the transfer of control of products or services. Revenue is measured as the amount of consideration expected to be received in exchange for transferring goods or providing services. Sales, value add, and other taxes the company collects concurrent with revenue-producing activities are excluded from revenue.

Sales of ethanol, distillers grains, corn oil, natural gas and other commodities by the company’s marketing business are recognized when obligations under the terms of a contract with a customer are satisfied. Generally, this occurs with the transfer of control of products or services. Revenues related to marketing for third parties are presented on a gross basis as the company controls the product prior to the sale to the end customer, takes title of the product and has inventory risk. Unearned revenue is recorded for goods in transit when the company has received payment but control has not yet been transferred to the customer. Revenues for receiving, storing, transferring and transporting ethanol and other fuels are recognized when the product is delivered to the customer.

The company routinely enters into physical-delivery energy commodity purchase and sale agreements. At times, the company settles these transactions by transferring its obligations to other counterparties rather than delivering the physical commodity. Energy trading transactions are reported net as a component of revenue. Revenues include net gains or losses from derivatives related to products sold while cost of goods sold includes net gains or losses from derivatives related to commodities purchased. Revenues also include realized gains and losses on related derivative financial instruments and reclassifications of realized gains and losses on cash flow hedges from accumulated other comprehensive income or loss.

Sales of products, including agricultural commodities, are recognized when control of the product is transferred to the customer, which depends on the agreed upon shipment or delivery terms. Revenues related to grain merchandising are presented gross and include shipping and handling, which is also a component of cost of goods sold. Revenues from grain storage are recognized over time as the services are rendered.

9

Revenues related to the design, engineering and installation of equipment are recognized over the term of the related contracts as equipment is delivered and installed and services are performed.

A substantial portion of the partnership revenues are derived from fixed-fee commercial agreements for storage, terminal or transportation services. The partnership recognizes revenue upon transfer of control of product from its storage tanks and fuel terminals, when railcar volumetric capacity is provided, and as truck transportation services are performed. To the extent shortfalls associated with minimum volume commitments in the previous four quarters continue to exist, volumes in excess of the minimum volume commitment are applied to those shortfalls. Remaining excess volumes generating operating lease revenue are recognized as incurred.

Shipping and Handling Costs

The company accounts for shipping and handling activities related to contracts with customers as costs to fulfill its promise to transfer the associated products. Accordingly, the company records customer payments associated with shipping and handling costs as a component of revenue, and classifies such costs as a component of cost of goods sold.

Cost of Goods Sold

Cost of goods sold includes direct labor, materials, shipping and plant overhead costs. Direct labor includes all compensation and related benefits of non-management personnel involved in ethanol production. Grain purchasing and receiving costs, excluding labor costs for grain buyers and scale operators, are also included in cost of goods sold. Materials include the cost of corn feedstock, denaturant, and process chemicals. Corn feedstock costs include gains and losses on related derivative financial instruments not designated as cash flow hedges, inbound freight charges, inspection costs and transfer costs, as well as reclassifications of gains and losses on cash flow hedges from accumulated other comprehensive income or loss. Plant overhead consists primarily of plant utilities, repairs and maintenance and outbound freight charges. Shipping costs incurred by the company, including railcar costs, are also reflected in cost of goods sold.

The company uses exchange-traded futures and options contracts and forward purchase and sale contracts to attempt to minimize the effect of price changes on ethanol, grain, corn oil and natural gas. Exchange-traded futures and options contracts are valued at quoted market prices and settled predominantly in cash. The company is exposed to loss when counterparties default on forward purchase and sale contracts. Grain inventories held for sale and forward purchase and sale contracts are valued at market prices when available or other market quotes adjusted for basis differences, primarily in transportation, between the exchange-traded market and local market where the terms of the contract are based. Changes in forward purchase contracts and exchange-traded futures and options contracts are recognized as a component of cost of goods sold.

Operations and Maintenance Expenses

In the partnership segment, transportation expenses represent the primary component of operations and maintenance expenses. Transportation expenses include railcar leases, freight and shipping of the company’s ethanol and co-products, as well as costs incurred storing ethanol at destination terminals.

Derivative Financial Instruments

The company uses various derivative financial instruments, including exchange-traded futures and exchange-traded and over-the-counter options contracts, to attempt to minimize risk and the effect of commodity price changes, including, but not limited to, corn, ethanol, natural gas, soybean meal and soybean oil. The company monitors and manages this exposure as part of its overall risk management policy to reduce the adverse effect market volatility may have on its operating results. The company may hedge these commodities as one way to mitigate risk; however, there may be situations when these hedging activities themselves result in losses.

10

By using derivatives to hedge exposures to changes in commodity prices, the company is exposed to credit and market risk. The company’s exposure to credit risk includes the counterparty’s failure 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 their financial condition. 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 parameters to monitor exposure within its risk management strategy, which limits the types of derivative instruments and strategies the company can use and the degree of market risk it can take using derivative instruments.

The company evaluates its physical delivery contracts to determine if they qualify for normal purchase or sale exemptions which are expected to be used or sold over a reasonable period in the normal course of business. Contracts that do not meet the normal purchase or sale criteria are recorded at fair value. Changes in fair value are recorded in operating income unless the contracts qualify for, and the company elects, cash flow hedge accounting treatment.

Certain qualifying derivatives related to ethanol production and agribusiness and energy services are designated as cash flow hedges. The company evaluates the derivative instrument to ascertain its effectiveness prior to entering into cash flow hedges. Unrealized gains and losses are reflected in accumulated other comprehensive income or loss until the gain or loss from the underlying hedged transaction is realized and the physical transaction is completed. When it becomes probable a forecasted transaction will not occur, the cash flow hedge treatment is discontinued, which affects earnings. These derivative financial instruments are recognized in current assets or current liabilities at fair value.

At times, the company hedges its exposure to changes in inventory values and designates qualifying derivatives as fair value hedges. The carrying amount of the hedged inventory is adjusted in the current period for changes in fair value. Estimated fair values carried at market are based on exchange-quoted prices, adjusted as appropriate for regional location basis values, which represent differences in local markets, including transportation as well as quality or grade differences. Basis values are generally determined using inputs from broker quotations or other market transactions. However, a portion of the value may be derived using unobservable inputs. Ineffectiveness of the hedges is recognized in the current period to the extent the change in fair value of the inventory is not offset by the change in fair value of the derivative.

Recent Accounting Pronouncements

On January 1, 2021, the company early adopted the amended guidance in ASC 470-20, Debt - Debt with Conversion and Other Options and ASC 815-40, Derivatives and Hedging - Contracts in Entity’s Own Equity - Accounting for Convertible Instruments and Contracts in an Equity’s Own Equity. The adoption of this guidance resulted in a $49.5 million decrease in additional paid-in capital, an $11.4 million increase in retained earnings and a $38.1 million increase in long-term debt, which included a $39.4 million increase in debt principal offset by a $1.3 million increase in debt issuance costs, resulting from amounts previously bifurcated to equity being reclassified to debt. See Note 8 – Debt and Note 11 – Stockholders’ Equity for further details.

In March 2020, the FASB issued amended guidance in ASC 848, Reference Rate Reform - Facilitation of the Effects of Reference Rate Reform on Financial Reporting, and a subsequent update in January 2021, which provides optional expedients and exceptions to U.S. GAAP guidance on contract modifications and hedge accounting to ease the financial reporting burden related to the expected market transition from the LIBOR and other interbank offered rates to alternative reference rates. The expedients and exceptions provided by the amended guidance do not apply to contract modifications made and hedging relationships entered into or evaluated after December 31, 2022, except for hedging relationships existing as of December 31, 2022, that an entity has elected certain optional expedients for and that are retained through the end of the hedging relationship. The guidance is effective upon issuance and to be applied prospectively from any date beginning March 12, 2020 through December 31, 2022. The amended guidance is not expected to have a material impact on the company’s consolidated financial statements.

In December 2019, the FASB issued amended guidance in ASC 740, Income Taxes - Simplifying the Accounting for Income Taxes, which simplifies the accounting for income taxes by removing certain exceptions to the general principles in ASC 740. The amendments also improve consistent application of and simplify U.S. GAAP for other areas of ASC 740 by clarifying and amending existing guidance. The amendments are effective for fiscal years beginning after December 15, 2021, and interim periods within fiscal years beginning after December 15, 2022. Early adoption of the amendments is permitted. The amended guidance is not expected to have a material impact on the company’s consolidated financial statements.

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2. REVENUE

Revenue Recognition

Revenue is recognized when obligations under the terms of a contract with a customer are satisfied. Generally, this occurs with the transfer of control of products or services. Revenue is measured as the amount of consideration expected to be received in exchange for transferring goods or providing services. Sales, value add, and other taxes the company collects concurrent with revenue-producing activities are excluded from revenue.

Revenue by Source

The following tables disaggregate revenue by major source (in thousands):

	Three Months Ended September 30, 2021
	Ethanol Production		Agribusiness & Energy Services		Partnership		Eliminations		Total
Revenues:
Revenues from contracts with customers under ASC 606:
Ethanol	$	-	$	-	$	-	$	-	$	-
Distillers grains		6,936		-		-		-		6,936
Corn oil		-		-		-		-		-
Service revenues		520		-		1,019		-		1,539
Other		8,633		9,597		-		-		18,230
Intersegment revenues		-		-		1,969		(1,969)		-
Total revenues from contracts with customers		16,089		9,597		2,988		(1,969)		26,705
Revenues from contracts accounted for as derivatives under ASC 815 (1):
Ethanol		455,843		109,552		-		-		565,395
Distillers grains		77,008		9,699		-		-		86,707
Corn oil		35,363		11,222		-		-		46,585
Grain		-		13,505		-		-		13,505
Other		4,046		3,837		-		-		7,883
Intersegment revenues		-		5,362		-		(5,362)		-
Total revenues from contracts accounted for as derivatives		572,260		153,177		-		(5,362)		720,075
Leasing revenues under ASC 842 (2):		-		-		16,263		(16,252)		11
Total Revenues	$	588,349	$	162,774	$	19,251	$	(23,583)	$	746,791

	Nine Months Ended September 30, 2021
	Ethanol Production		Agribusiness & Energy Services		Partnership		Eliminations		Total
Revenues:
Revenues from contracts with customers under ASC 606:
Ethanol	$	-	$	-	$	-	$	-	$	-
Distillers grains		14,974		-		-		-		14,974
Corn oil		-		-		-		-		-
Service revenues		2,545		-		3,235		-		5,780
Other		25,062		12,640		-		-		37,702
Intersegment revenues		-		-		6,147		(6,147)		-
Total revenues from contracts with customers		42,581		12,640		9,382		(6,147)		58,456
Revenues from contracts accounted for as derivatives under ASC 815 (1):
Ethanol		1,159,020		324,395		-		-		1,483,415
Distillers grains		268,167		27,953		-		-		296,120
Corn oil		75,252		23,808		-		-		99,060
Grain		-		36,473		-		-		36,473
Other		22,324		28,939		-		-		51,263
Intersegment revenues		-		15,997		-		(15,997)		-
Total revenues from contracts accounted for as derivatives		1,524,763		457,565		-		(15,997)		1,966,331
Leasing revenues under ASC 842 (2):		-		-		49,976		(49,914)		62
Total Revenues	$	1,567,344	$	470,205	$	59,358	$	(72,058)	$	2,024,849

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	Three Months Ended September 30, 2020
	Ethanol Production		Agribusiness & Energy Services		Partnership		Eliminations		Total
Revenues:
Revenues from contracts with customers under ASC 606:
Ethanol	$	-	$	-	$	-	$	-	$	-
Distillers grains		4,095		-		-		-		4,095
Corn oil		-		2,938		-		-		2,938
Service revenues		-		-		920		-		920
Other		66		1,408		-		-		1,474
Intersegment revenues		25		-		2,289		(2,314)		-
Total revenues from contracts with customers		4,186		4,346		3,209		(2,314)		9,427
Revenues from contracts accounted for as derivatives under ASC 815 (1):
Ethanol		263,390		56,895		-		-		320,285
Distillers grains		51,692		10,696		-		-		62,388
Corn oil		12,433		5,805		-		-		18,238
Grain		1		11,099		-		-		11,100
Other		1,276		1,233		-		-		2,509
Intersegment revenues		-		5,354		-		(5,354)		-
Total revenues from contracts accounted for as derivatives		328,792		91,082		-		(5,354)		414,520
Leasing revenues under ASC 842 (2):		-		-		18,173		(18,058)		115
Total Revenues	$	332,978	$	95,428	$	21,382	$	(25,726)	$	424,062

	Nine Months Ended September 30, 2020
	Ethanol Production		Agribusiness & Energy Services		Partnership		Eliminations		Total
Revenues:
Revenues from contracts with customers under ASC 606:
Ethanol	$	-	$	-	$	-	$	-	$	-
Distillers grains		25,159		-		-		-		25,159
Corn oil		-		2,938		-		-		2,938
Service revenues		-		-		3,366		-		3,366
Other		4,257		3,668		-		-		7,925
Intersegment revenues		75		-		6,201		(6,276)		-
Total revenues from contracts with customers		29,491		6,606		9,567		(6,276)		39,388
Revenues from contracts accounted for as derivatives under ASC 815 (1):
Ethanol		849,298		243,930		-		-		1,093,228
Distillers grains		179,854		28,960		-		-		208,814
Corn oil		36,621		23,681		-		-		60,302
Grain		7		26,773		-		-		26,780
Other		3,974		12,128		-		-		16,102
Intersegment revenues		-		17,030		-		(17,030)		-
Total revenues from contracts accounted for as derivatives		1,069,754		352,502		-		(17,030)		1,405,226
Leasing revenues under ASC 840 (2):		-		-		52,467		(52,126)		341
Total Revenues	$	1,099,245	$	359,108	$	62,034	$	(75,432)	$	1,444,955

(1)Revenues from contracts accounted for as derivatives represent physically settled derivative sales that are outside the scope of ASC 606, where the company recognizes revenue when control of the inventory is transferred within the meaning of ASC 606 as required by ASC 610-20, Gains and Losses from Derecognition of Nonfinancial Assets.

(2)Leasing revenues do not represent revenues recognized from contracts with customers under ASC 606, and are accounted for under ASC 842, Leases.

Major Customers

For the three and nine months ended September 30, 2021, no single customer’s revenue was over 10% of total revenues. No single customer’s revenue was over 10% of total revenues for the three months ended September 30, 2020, while revenues from Customer A represented approximately 10% of total revenues for the nine months ended September 30, 2020, which are reported in the ethanol production segment.

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3. ACQUISITIONS AND DISPOSITIONS

Acquisition of a Majority Interest in Fluid Quip Technologies, LLC

On December 9, 2020, the company acquired a majority interest in Fluid Quip Technologies, LLC. During the second quarter of 2021, the company identified additional information through analysis of the final FQT acquisition agreements that resulted in a reassessment of certain contingent considerations related to potential earn-out payments which identified an understatement of other long term assets by $16.7 million, accrued liabilities of $2.4 million, long term other liabilities of $12.4 million and noncontrolling interests of $1.9 million as previously reported within ethanol production segment as of March 31, 2021 and December 31, 2020.

Disposition of Ord Ethanol Plant

On March 22, 2021, the company completed the sale of the plant located in Ord, Nebraska and certain related assets, to GreenAmerica Biofuels Ord LLC (the “Ord Transaction”) for a sale price of $64.0 million, plus working capital of $9.8 million. Correspondingly, the company entered into a separate asset purchase agreement with the Partnership to acquire the storage assets and assign the rail transportation assets to be disposed of in the Ord Transaction for $27.5 million, which was used to pay down a portion of the partnership’s credit facility. The divested assets were reported within the company’s ethanol production, agribusiness and energy services and partnership segments. The company recorded a pretax gain on the sale of the Ord plant of $35.9 million within corporate activities.

The asset and liabilities of the Ord ethanol plant at closing on March 22, 2021 were as follows: (in thousands):

Amounts of Identifiable Assets Disposed and Liabilities Relinquished
Inventory		$	10,400
Prepaid expenses and other			632
Property and equipment			24,285
Operating lease right-of-use assets			1,811
Accrued and other liabilities			(156)
Operating lease current liabilities			(1,021)
Operating lease long-term liabilities			(790)
	Total identifiable net assets disposed	$	35,161

The amounts reflected above represent working capital estimates, which are considered preliminary until contractual post-closing working capital adjustments are finalized.

Disposition of Hereford Ethanol Plant

On December 28, 2020, the company completed the sale of the plant located in Hereford, Texas, and certain related assets, to Hereford Ethanol Partners, L.P. There were no material changes to the assets disposed and liabilities relinquished from the disposition of the Hereford plant during the three and nine months ended September 30, 2021.

Disposition of Equity Interest in Green Plains Cattle Company LLC

On October 1, 2020, pursuant to the Securities Purchase Agreement, the company sold its remaining 50% joint venture interest in GPCC to AGR, TGAM Agribusiness Fund LP and StepStone (the “Buyers”) for $80.5 million in cash, plus closing adjustments. The transaction resulted in a reduction in other assets of $69.7 million as a result of the removal of the equity method investment in GPCC, and a reduction in accumulated other comprehensive income (loss) of $10.7 million as a result of the removal of the company’s share of equity method investees accumulated other comprehensive loss. Transaction fees related to the disposal were not material. The Securities Purchase Agreement contains certain earn-out provisions of up to $4.0 million to be paid to the Buyers if certain EBITDA thresholds are met. During the three months ended September 30, 2021, the company recorded an estimated loss of $2.0 million associated with the earn-out provision, and will record any additional contingent amounts associated with the earn-out provision in the consolidated financial statements when the amount is reasonably determinable.

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4. 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 the company can access at the measurement date.

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 through correlation or other means. Grain inventories held for sale in the agribusiness and energy services segment are valued at nearby futures values, plus or minus nearby basis values, which represent differences in local markets, including transportation or commodity quality or grade differences.

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

Derivative contracts include exchange-traded commodity futures and options contracts and forward commodity purchase and sale contracts. Exchange-traded futures and options contracts are valued based on unadjusted quoted prices in active markets and are classified in Level 1. The majority of the company’s exchange-traded futures and options contracts are cash-settled on a daily basis.

There have been no changes in valuation techniques and inputs used in measuring fair value. The company’s assets and liabilities by level are as follows (in thousands):

	Fair Value Measurements at September 30, 2021
	Quoted Prices in ‎ Active Markets for ‎Identical Assets		Significant Other ‎Observable Inputs
	(Level 1)		(Level 2)		Total
Assets:
Cash and cash equivalents	$	589,822	$	-	$	589,822
Restricted cash		131,073		-		131,073
Inventories carried at market		-		41,456		41,456
Unrealized gains on derivatives		-		45,691		45,691
Other assets		111		94		205
Total assets measured at fair value	$	721,006	$	87,241	$	808,247
Liabilities:
Accounts payable (1)	$	-	$	18,732	$	18,732
Accrued and other liabilities (2)		-		3,377		3,377
Unrealized losses on derivatives		-		11,730		11,730
Other liabilities (2)		-		9,320		9,320
Total liabilities measured at fair value	$	-	$	43,159	$	43,159

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	Fair Value Measurements at December 31, 2020
	Quoted Prices in ‎ Active Markets for ‎Identical Assets		Significant Other ‎Observable Inputs
	(Level 1)		(Level 2)		Total
Assets:
Cash and cash equivalents	$	233,860	$	-	$	233,860
Restricted cash		40,950		-		40,950
Inventories carried at market		-		77,900		77,900
Unrealized gains on derivatives		-		21,956		21,956
Other assets		112		29		141
Total assets measured at fair value	$	274,922	$	99,885	$	374,807
Liabilities:
Accounts payable (1)	$	-	$	19,355	$	19,355
Unrealized losses on derivatives		-		10,997		10,997
Total liabilities measured at fair value	$	-	$	30,352	$	30,352

(1)Accounts payable is generally stated at historical amounts with the exception of $18.7 million and $19.4 million at September 30, 2021 and December 31, 2020, respectively, related to certain delivered inventory for which the payable fluctuates based on changes in commodity prices. These payables are hybrid financial instruments for which the company has elected the fair value option.

(2)As of September 30, 2021, accrued and other liabilities includes $3.4 million and other liabilities includes $9.3 million of consideration related to potential earn-out payments recorded at fair value.

The fair value of the company’s debt was approximately $858.9 million compared with a book value of $711.4 million, excluding debt issuance costs, at September 30, 2021. The fair value of the company’s debt was approximately $535.9 million compared with a book value of $526.2 million at December 31, 2020. The company estimated the fair value of its convertible notes using Level 1 inputs, and the fair value of its other outstanding debt using Level 2 inputs. The company believes the fair values of its accounts receivable approximated book value, which was $90.3 million and $55.6 million at September 30, 2021 and December 31, 2020, respectively.

Although the company currently does not have any recurring Level 3 financial measurements, the fair values of tangible and intangible assets and goodwill acquired represent Level 3 measurements which were derived using a combination of the income approach, market approach and cost approach for the specific assets or liabilities being valued.

5. SEGMENT INFORMATION

The company reports the financial and operating performance for the following four operating segments: (1) ethanol production, which includes the production of ethanol, including industrial-grade alcohol, distillers grains, Ultra-High Protein and corn oil, (2) agribusiness and energy services, which includes grain handling and storage, commodity marketing and merchant trading for company-produced and third-party ethanol, distillers grains, corn oil, natural gas and other commodities, (3) food and ingredients, which includes food-grade corn oil and (4) partnership, which includes fuel storage and transportation services. The food and ingredients segment, had no activity during the three and nine months ended September 30, 2021 and 2020.

Corporate activities include selling, general and administrative expenses, consisting primarily of compensation, professional fees and overhead costs not directly related to a specific operating segment.

During the normal course of business, the operating segments conduct business with each other. For example, the agribusiness and energy services segment procures grain and natural gas and sells products, including ethanol, distillers grains and corn oil for the ethanol production segment. The partnership segment provides fuel storage and transportation services for the ethanol production segment. These intersegment activities are treated like third-party transactions with origination, marketing and storage fees charged at estimated market values. Consequently, these transactions affect segment performance; however, they do not impact the company’s consolidated results since the revenues and corresponding costs are eliminated.
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The following tables set forth certain financial data for the company’s operating segments (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Revenues:
Ethanol production:
Revenues from external customers	$	588,349	$	332,953	$	1,567,344	$	1,099,170
Intersegment revenues		-		25		-		75
Total segment revenues		588,349		332,978		1,567,344		1,099,245
Agribusiness and energy services:
Revenues from external customers		157,412		90,074		454,208		342,078
Intersegment revenues		5,362		5,354		15,997		17,030
Total segment revenues		162,774		95,428		470,205		359,108
Partnership:
Revenues from external customers		1,030		1,035		3,297		3,707
Intersegment revenues		18,221		20,347		56,061		58,327
Total segment revenues		19,251		21,382		59,358		62,034
Revenues including intersegment activity		770,374		449,788		2,096,907		1,520,387
Intersegment eliminations		(23,583)		(25,726)		(72,058)		(75,432)
Total Revenues	$	746,791	$	424,062	$	2,024,849	$	1,444,955

Refer to Note 2 - Revenue, for further disaggregation of revenue by operating segment.

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Cost of goods sold:
Ethanol production	$	597,854	$	330,162	$	1,507,035	$	1,103,486
Agribusiness and energy services		154,427		87,027		440,682		339,332
Intersegment eliminations		(22,102)		(23,256)		(68,897)		(70,761)
	$	730,179	$	393,933	$	1,878,820	$	1,372,057

	Three Months Ended ‎September 30,				Nine Months Ended ‎September 30,
	2021		2020		2021		2020
Operating income (loss):
Ethanol production (1)	$	(44,192)	$	(21,351)	$	(30,969)	$	(100,924)
Agribusiness and energy services		3,225		4,296		15,720		7,207
Partnership		12,417		12,986		37,204		37,641
Intersegment eliminations		(1,481)		(2,447)		(3,161)		(4,597)
Corporate activities (2)		(14,644)		(7,689)		(1,089)		(27,228)
	$	(44,675)	$	(14,205)	$	17,705	$	(87,901)

(1)Operating loss for ethanol production includes a goodwill impairment charge of $24.1 million for the nine months ended September 30, 2020.

(2)Corporate activities for the three and nine months ended September 30, 2021 include a $1.8 million loss on sale of assets and a $31.2 million gain on sale of assets, respectively, as well as a gain on sale of assets of $2.0 million for both the three and nine months ended September 30, 2020.

	Three Months Ended ‎September 30,				Nine Months Ended ‎September 30,
	2021		2020		2021		2020
Depreciation and amortization:
Ethanol production	$	25,644	$	17,493	$	62,655	$	50,575
Agribusiness and energy services		870		655		2,072		1,764
Partnership		1,089		940		2,771		2,867
Corporate activities		677		665		1,995		2,002
	$	28,280	$	19,753	$	69,493	$	57,208

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The following table sets forth total assets by operating segment (in thousands):

	September 30, 2021		December 31, 2020
Total assets (1):
Ethanol production	$	1,069,056	$	900,963
Agribusiness and energy services		429,450		378,720
Partnership		102,116		91,205
Corporate assets		552,040		228,074
Intersegment eliminations		(39,458)		(20,045)
	$	2,113,204	$	1,578,917

(1)Asset balances by segment exclude intercompany balances.  

6. INVENTORIES

Inventories are carried at the lower of cost or net realizable value, except grain held for sale and fair-value hedged inventories. Commodities held for sale are reported at market value. There was no lower of cost or net realizable value inventory adjustment as of September 30, 2021 and December 31, 2020.

The components of inventories are as follows (in thousands):

	September 30, 2021		December 31, 2020
Finished goods	$	98,044	$	89,223
Commodities held for sale		33,835		40,147
Raw materials		57,342		90,800
Work-in-process		19,356		13,201
Supplies and parts		34,630		36,120
	$	243,207	$	269,491

7. DERIVATIVE FINANCIAL INSTRUMENTS

At September 30, 2021, the company’s consolidated balance sheet reflected unrealized gains of $1.0 million, net of tax, in accumulated other comprehensive income (loss). The company expects these losses will be reclassified to operating income over the next 12 months as a result of hedged transactions that are forecasted to occur. The amount realized in operating income will differ as commodity prices change.

Fair Values of Derivative Instruments

The fair values of the company’s derivative financial instruments and the line items on the consolidated balance sheets where they are reported are as follows (in thousands):

	Asset Derivatives'					Liability Derivatives'
	Fair Value					Fair Value
	September 30, ‎2021		December 31, ‎2020			September 30, ‎2021			December 31, ‎2020
Derivative financial instruments	$	45,691	$	21,956	(1)	$	11,730	(2)	$	10,997	(3)
Other assets		94		29			-			-
Total	$	45,785	$	21,985		$	11,730		$	10,997

(1)At December 31, 2020, derivative financial instruments, as reflected on the balance sheet, includes net unrealized gains on exchange traded futures and options contracts of $3.3 million, which included $2.8 million of net unrealized gains on derivative financial instruments designated as cash flow hedging instruments.

(2)At September 30, 2021, derivative financial instruments, as reflected on the balance sheet, includes net unrealized losses on exchange traded futures and options contracts of $23.7 million, which included $14.3 million of net unrealized losses on derivative financial instruments designated as cash flow hedging instruments.

(3)At December 31, 2020, derivative financial instruments, as reflected on the balance sheet, includes net unrealized losses on exchange traded futures and options contracts of $9.3 million, none of which were designated as cash flow hedging instruments.

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Refer to Note 4 - Fair Value Disclosures, which contains fair value information related to derivative financial instruments.

Effect of Derivative Instruments on Consolidated Balance Sheets, Consolidated Statements of Operations and Consolidated Statements of Comprehensive Income

The gains or losses recognized in income and other comprehensive income related to the company’s derivative financial instruments and the line items on the consolidated financial statements where they are reported are as follows (in thousands):

	Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income into Income
Location of Gain (Loss) Reclassified from Accumulated Other	Three Months Ended ‎September 30,				Nine Months Ended ‎September 30,
Comprehensive Income into Income	2021		2020		2021		2020
Revenues	$	(691)	$	-	$	(39,571)	$	8,824
Cost of goods sold		947		-		36,431		(2,901)
Net gain (loss) recognized in income (loss) before income taxes	$	256	$	-	$	(3,140)	$	5,923

	Amount of Gain (Loss) Recognized in Other Comprehensive Income on Derivatives
Gain (Loss) Recognized in Other Comprehensive Income on	Three Months Ended ‎September 30,				Nine Months Ended ‎September 30,
Derivatives	2021		2020		2021		2020
Commodity contracts	$	709	$	(3,555)	$	1,080	$	663

		Amount of Gain (Loss)
		Recognized in Income on Derivatives
Derivatives Not Designated as	Location of Gain (Loss) Recognized in Income	Three Months Ended ‎September 30,				Nine Months Ended ‎September 30,
Hedging Instruments	on Derivatives	2021		2020		2021		2020
Commodity contracts	Revenues	$	1,638	$	(21,128)	$	(50,257)	$	8,681
Commodity contracts	Costs of goods sold		(7,594)		4,184		3,960		10,678
Net gain (loss) recognized in income (loss) before income taxes		$	(5,956)	$	(16,944)	$	(46,297)	$	19,359

The following amounts were recorded on the consolidated balance sheets related to cumulative basis adjustments for the fair value hedged items (in thousands):

	September 30, 2021				December 31, 2020
Line Item in the Consolidated Balance Sheet in Which the Hedged Item is Included	Carrying Amount of the Hedged Assets		Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of the Hedged Assets		Carrying Amount of the Hedged Assets		Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of the Hedged Assets
Inventories	$	41,456	$	14,734	$	53,963	$	9,041

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Effect of Cash Flow and Fair Value Hedge Accounting on the Statements of Operations

The effect of cash flow and fair value hedges and the line items on the consolidated statements of operations where they are reported are as follows (in thousands):

	Location and Amount of Gain (Loss) Recognized in Income on Cash Flow and Fair Value Hedging Relationships for the Three Months Ended September 30,
		2021				2020
	Revenue		Cost of ‎Goods Sold			Revenue	Cost of ‎Goods Sold
Gain (loss) on cash flow hedging relationships:
Commodity contracts:
Amount of gain (loss) reclassified from accumulated other comprehensive income into income	$	(691)	$	947	$	-	$	-
Gain (loss) on fair value hedging relationships:
Commodity contracts:
Hedged item		-		10,359		-		4,264
Derivatives designated as hedging instruments		-		(10,726)		-		(5,380)
Total amounts of income and expense line items presented in the statement of operations in which the effects of cash flow or fair value hedges are recorded	$	(691)	$	580	$	-	$	(1,116)

	Location and Amount of Gain (Loss) Recognized in
	Income on Cash Flow and Fair Value Hedging
	Relationships for the Nine Months Ended September 30,
		2021				2020
	Revenue		Cost of ‎Goods Sold		Revenue		Cost of ‎Goods Sold
Gain (loss) on cash flow hedging relationships:
Commodity contracts:
Amount of gain (loss) reclassified from accumulated other comprehensive income into income	$	(39,571)	$	36,431	$	8,824	$	(2,901)
Gain (loss) on fair value hedging relationships:
Commodity contracts:
Hedged item		-		28,732		-		(3,665)
Derivatives designated as hedging instruments		-		(25,078)		-		3,220
Total amounts of income and expense line items presented in the statement of operations in which the effects of cash flow or fair value hedges are recorded	$	(39,571)	$	40,085	$	8,824	$	(3,346)

There were no gains or losses from discontinuing cash flow or fair value hedge treatment during the three and nine months ended September 30, 2021 and 2020.

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20

The open commodity derivative positions as of September 30, 2021, are as follows (in thousands):

	Exchange Traded (1)		Non-Exchange Traded (2)
Derivative ‎Instruments	Net Long & ‎(Short)		Long	(Short)	Unit of ‎Measure	Commodity
Futures	(29,345)				Bushels	Corn
Futures	56,130	(3)			Bushels	Corn
Futures	(1,360)	(4)			Bushels	Corn
Futures	(23,436)				Gallons	Ethanol
Futures	(160,104)	(3)			Gallons	Ethanol
Futures	(15,430)				MmBTU	Natural Gas
Futures	1,888	(3)			MmBTU	Natural Gas
Futures	(6,055)	(4)			MmBTU	Natural Gas
Options	36,205				Pounds	Soybean Oil
Options	2,665				Bushels	Corn
Options	(2,511)				MmBTU	Natural Gas
Forwards			42,008	(108)	Bushels	Corn
Forwards			1,159	(357,410)	Gallons	Ethanol
Forwards			99	(612)	Tons	Distillers Grains
Forwards			2,496	(71,617)	Pounds	Corn Oil
Forwards			16,532	(295)	MmBTU	Natural Gas

(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.

(4)Futures used for fair value hedges.

Energy trading contracts that do not involve physical delivery are presented net in revenues on the consolidated statements of operations. Included in revenues are net gains on energy trading contracts of $0.1 million and $0.6 million for the three and nine months ended September 30, 2021, respectively, and net losses on energy trading contracts of $0.9 million and net gains on energy trading contracts of $2.1 million for the three and nine months ended September 30, 2020, respectively.

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8. DEBT

On January 1, 2021, the company early adopted the amended guidance in ASC 470-20, using the modified retrospective method of transition. The adoption of this guidance resulted in a $49.5 million decrease in additional paid-in capital, an $11.4 million increase in retained earnings and a $38.1 million increase in long-term debt, which included a $39.4 million increase in debt principal offset by a $1.3 million increase in debt issuance costs, resulting from amounts previously bifurcated to equity being reclassified to debt.

The components of long-term debt are as follows (in thousands):

	September 30, 2021		December 31, 2020
Corporate: (1)
2.25% convertible notes due 2027 (2)	$	230,000	$	-
4.00% convertible notes due 2024 (3)		64,000		89,125
4.125% convertible notes due 2022 (4)		34,316		156,441
Green Plains SPE LLC:
$125.0 million junior secured mezzanine notes due 2026 (5)		125,000		-
Green Plains Wood River and Green Plains Shenandoah:
$75.0 million delayed draw loan agreement (6)		30,000		30,000
Green Plains Partners:
$60.0 million credit facility (7)		60,000		100,000
Other		15,580		15,936
Total book value of long-term debt		558,896		391,502
Unamortized debt issuance costs		(9,985)		(6,151)
Less: current maturities of long-term debt		(34,477)		(98,052)
Total long-term debt	$	514,434	$	287,299

(1)See discussion on early adoption of the amended guidance in ASC 470-20 above.

(2)Includes $6.8 million of unamortized debt issuance costs as of September 30, 2021.

(3)See discussion below regarding the exchange of convertible notes due in 2024. Includes $1.3 million and $2.2 million of unamortized debt issuance costs as of September 30, 2021 and December 31, 2020, respectively.

(4)See discussion below regarding the repurchase of convertible notes due in 2022. Includes $0.2 million and $1.3 million of unamortized debt issuance costs as of September 30, 2021 and December 31, 2020, respectively.

(5)Includes $0.9 million of unamortized debt issuance costs as of September 30, 2021.

(6)Includes $0.3 million of unamortized debt issuance costs as of both September 30, 2021 and December 31, 2020, respectively.

(7)The Green Plains Partners credit facility was amended on July 20, 2021, reducing the total amount available to $60.0 million and includes $0.4 million and $2.3 million of unamortized debt issuance costs as of September 30, 2021 and December 31, 2020, respectively.

The components of short-term notes payable and other borrowings are as follows (in thousands):

	September 30, 2021		December 31, 2020
Green Plains Trade:
$300.0 million revolver	$	109,624	$	79,251
Green Plains Grain:
$100.0 million revolver		22,800		38,700
$50.0 million inventory financing		-		-
Green Plains Commodity Management:
$30.0 million hedge line		30,046		21,682
Other		-		1,175
	$	162,470	$	140,808

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Corporate Activities

In March 2021, the company issued an aggregate $230.0 million of 2.25% convertible senior notes due in 2027, or the 2.25% notes. The 2.25% notes bear interest at a rate of 2.25% per year, payable on March 15 and September 15 of each year, beginning September 15, 2021, and mature on March 15, 2027. The 2.25% notes are senior, unsecured obligations of the company. The 2.25% notes are convertible, at the option of the holders, into consideration consisting of, at the company’s election, cash, shares of the company’s common stock, or a combination of cash and stock (and cash in lieu of fractional shares). However, before September 15, 2026, the 2.25% notes will not be convertible unless certain conditions are satisfied. The initial conversion rate is 31.6206 shares of the company’s common stock per $1,000 principal amount of 2.25% notes (equivalent to an initial conversion price of approximately $31.62 per share of the company’s common stock), representing an approximately 37.5% premium over the offering price of the company’s common stock. The conversion rate is subject to adjustment upon the occurrence of certain events, including but not limited to; the event of a stock dividend or stock split; the issuance of additional rights, options and warrants; spinoffs; the event of a cash dividend or distribution; or a tender or exchange offering. In addition, the company may be obligated to increase the conversion rate for any conversion that occurs in connection with certain corporate events, including the company’s calling the 2.25% notes for redemption.

On and after March 15, 2024, and prior to the maturity date, the company may redeem, for cash, all, but not less than all, of the 2.25% notes if the last reported sale price of the company’s common stock equals or exceeds 140% of the applicable conversion price on (i) at least 20 trading days during a 30 consecutive trading day period ending on the trading day immediately prior to the date the company delivers notice of the redemption; and (ii) the trading day immediately before the date of the redemption notice. The redemption price will equal 100% of the principal amount of the 2.25% notes to be redeemed, plus any accrued and unpaid interest to, but excluding, the redemption date. In addition, upon the occurrence of a “fundamental change” (as defined in the indenture for the 2.25% notes), holders of the 2.25% notes will have the right, at their option, to require the company to repurchase their 2.25% notes for cash at a price equal to 100% of the principal amount of the 2.25% notes to be repurchased, plus accrued and unpaid interest to, but excluding, the fundamental change repurchase date.

During June 2019, the company issued an aggregate $115.0 million of 4.00% convertible senior notes due in 2024, or the 4.00% notes. The 4.00% notes are senior, unsecured obligations of the company, with interest payable on January 1 and July 1 of each year, beginning January 1, 2020, at a rate of 4.00% per annum. The 4.00% notes will mature on July 1, 2024, unless earlier converted, redeemed or repurchased. The 4.00% notes will be convertible, at the option of the holders, into consideration consisting of, at the company’s election, cash, shares of the company’s common stock, or a combination of cash and shares of the company’s common stock until the close of business on the scheduled trading day immediately preceding the maturity date. However, before January 1, 2024, the 4.00% notes will not be convertible unless certain conditions are satisfied. The initial conversion rate is 64.1540 shares of common stock per $1,000 of principal, which is equal to a conversion price of approximately $15.59 per share. The conversion rate will be subject to adjustment upon the occurrence of certain events, including but not limited to; the event of a stock dividend or stock split; the issuance of additional rights, options and warrants; spinoffs; the event of a cash dividend or distribution; or a tender or exchange offering. In addition, the company may be obligated to increase the conversion rate for any conversion that occurs in connection with certain corporate events, including the company’s calling the 4.00% notes for redemption.

On and after July 1, 2022, and prior to the maturity date, the company may redeem all, but not less than all, of the 4.00% notes for cash if the sale price of the company’s common stock equals or exceeds 140% of the applicable conversion price for a specified time period ending on the trading day immediately prior to the date the company delivers notice of the redemption. The redemption price will equal 100% of the principal amount of the 4.00% notes to be redeemed, plus any accrued and unpaid interest to, but excluding, the redemption date. In addition, upon the occurrence of a fundamental change, holders of the 4.00% notes will have the right, at their option, to require the company to repurchase the 4.00% notes in cash at a price equal to 100% of the principal amount of the 4.00% notes to be repurchased, plus accrued and unpaid interest to, but excluding, the fundamental change repurchase date.

During May 2021, the company entered into a privately negotiated agreement with certain noteholders of the company’s 4.00% notes. Under this agreement, 3,568,705 shares of the company’s common stock were exchanged for $51.0 million in aggregate principal amount of the 4.00% notes. Common stock held as treasury shares were exchanged for the 4.00% notes. Pursuant to the guidance within ASC 470, Debt, the company recorded a loss of $9.5 million which was recorded as a charge to interest expense in the consolidated financial statements during the three months ended June 30, 2021, of which $1.2 million related to unamortized debt issuance costs.

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In August 2016, the company issued $170.0 million of 4.125% convertible senior notes due in 2022, or the 4.125% notes. The 4.125% notes are senior, unsecured obligations of the company, with interest payable on March 1 and September 1 of each year. The company may settle the 4.125% notes in cash, common stock or a combination of cash and common stock. Prior to March 1, 2022, the 4.125% notes are not convertible unless certain conditions are satisfied. The initial conversion rate is 35.7143 shares of common stock per $1,000 of principal, which is equal to a conversion price of approximately $28.00 per share. The conversion rate will be subject to adjustment upon the occurrence of certain events, including but not limited to; the event of a stock dividend or stock split; the issuance of additional rights, options and warrants; spinoffs; the event of a cash dividend or distribution; or a tender or exchange offering.

The company may redeem all, but not less than all, of the 4.125% notes at any time on or after September 1, 2020, if the company’s common stock equals or exceeds 140% of the applicable conversion price for a specified time period ending on the trading day immediately prior to the date the company delivers notice of the redemption. The redemption price will equal 100% of the principal plus any accrued and unpaid interest. Holders of the 4.125% notes have the option to require the company to repurchase the 4.125% notes in cash at a price equal to 100% of the principal plus accrued and unpaid interest when there is a fundamental change, such as change in control. If an event of default occurs, it could result in the 4.125% notes being declared due and payable.

In March 2021, concurrent with the issuance of the 2.25% notes, the company used approximately $156.5 million of the net proceeds of the 2.25% notes to repurchase approximately $135.7 million aggregate principal amount of the 4.125% notes, in privately negotiated transactions. Pursuant to the guidance within ASC 470, Debt, the company recorded a loss upon extinguishment of $22.1 million. This charge included $1.2 million of unamortized debt issuance costs related to the principal balance extinguished.

Agribusiness and Energy Services Segment

Green Plains Trade has a $300.0 million senior secured asset-based revolving credit facility to finance working capital for marketing and distribution activities based on eligible collateral equal to the sum of percentages of eligible receivables and inventories, less miscellaneous adjustments. The credit facility matures on July 28, 2022 and consists of a $285 million credit facility and a $15 million first-in-last-out (FILO) credit facility and includes an accordion feature that enables the credit facility to be increased by up to $70.0 million with agent approval. Advances are subject to variable interest rates equal to daily LIBOR plus 2.25% on the credit facility and daily LIBOR plus 3.25% on the FILO credit facility. The total unused portion of the revolving credit facility is also subject to a commitment fee of 0.375% per annum.

The terms impose affirmative and negative covenants for Green Plains Trade, including maintaining a minimum fixed charge coverage ratio of 1.15 to 1.00. Capital expenditures are limited to $1.5 million per year under the credit facility. The credit facility also restricts distributions related to capital stock, with an exception for distributions up to 50% of net income if, on a pro forma basis, (a) availability has been greater than $10.0 million for the last 30 days and (b) the borrower would be in compliance with the fixed charge coverage ratio on the distribution date.

Green Plains Grain has a $100.0 million senior secured asset-based revolving credit facility, which matures on June 28, 2022. The credit facility finances working capital up to the maximum commitment based on eligible collateral equal to the sum of percentages of eligible cash, receivables and inventories, less miscellaneous adjustments. Advances are subject to an interest rate equal to LIBOR plus 3.00% or the lenders’ base rate plus 2.00%. The credit facility also includes an accordion feature that enables the facility to be increased by up to $75.0 million with agent approval. The credit facility can also be increased by up to $50.0 million for seasonal borrowings. Total commitments outstanding cannot exceed $225.0 million. Depending on utilization, the total unused portion of the $100.0 million revolving credit facility is also subject to a commitment fee ranging from 0.375% to 0.50%.

Lenders receive a first priority lien on certain cash, inventory, accounts receivable and other assets owned by Green Plains Grain. The terms impose affirmative and negative covenants for Green Plains Grain, including maintaining minimum working capital to be the greater of (i) $18,000,000 and (ii) 18% of the sum of the then total commitment plus the aggregate seasonal line commitments. Minimum tangible net worth is required to be greater than 21% of the sum of the then total commitment plus the aggregate seasonal line commitments. The credit facility also requires the company to maintain a maximum annual leverage of 6.00 to 1.00. Capital expenditures are limited to $8.0 million per year under the credit facility, plus equity contributions from the company and unused amounts of up to $8.0 million from the previous year. In addition, if the company has long-term indebtedness on the date of calculation of greater than $10.0 million, the credit facility requires the company to maintain a minimum fixed charge coverage ratio of 1.25 to 1.00 and a maximum long term debt capitalization of 40%.  

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Green Plains Grain has entered into a $50.0 million short-term inventory financing agreement with a financial institution. 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. The company had no short-term notes payable related to these inventory financing agreements as of September 30, 2021.

Green Plains Commodity Management has an uncommitted $30.0 million revolving credit facility which matures April 30, 2023, to finance margins related to its hedging programs. Advances are subject to variable interest rates equal to LIBOR plus 1.75%.

Ethanol Production Segment

On February 9, 2021, Green Plains SPE LLC, a wholly-owned special purpose subsidiary and parent of Green Plains Obion and Green Plains Mount Vernon, issued $125.0 million of junior secured mezzanine notes due 2026 (the “Junior Notes”) with BlackRock, a holder of a portion of the company’s common stock, for the purchase of all notes issued.

The Junior Notes will mature on February 9, 2026 and are secured by a pledge of the membership interests in and the real property owned by Green Plains Obion and Green Plains Mount Vernon. The proceeds of the Junior Notes will be used to construct high protein processing systems at the Green Plains Obion and Green Plains Mount Vernon facilities. The Junior Notes accrue interest at an annual rate of 11.75%. However, subject to the satisfaction of certain conditions, the Green Plains SPE LLC may elect to pay an amount in cash equal to interest accruing at a rate of 6.00% per annum plus an amount equal to interest accruing at a rate of 6.75% per annum to be paid in kind. The entire outstanding principal balance, plus any accrued and unpaid interest is due upon maturity. Green Plains SPE LLC is required to comply with certain financial covenants regarding minimum liquidity at Green Plains and a maximum aggregate loan to value. The Junior Notes can be retired or refinanced after 42 months with no prepayment premium. The Junior Notes have an unsecured parent guarantee from the company and have certain limitations on distributions, dividends or loans to the company unless there will not exist any event of default. Funds associated with the Junior Notes are administered by a trustee and are included in the balance of restricted cash as of September 30, 2021.

On September 3, 2020, Green Plains Wood River and Green Plains Shenandoah, wholly-owned subsidiaries of the company, entered into a delayed draw loan agreement with MetLife Real Estate Lending LLC. The $75.0 million delayed draw loan matures on September 1, 2035 and is secured by substantially all of the assets of the Wood River and Shenandoah facilities. The proceeds from the loan will be used to add high protein processing systems at the Wood River and Shenandoah facilities as well as other capital expenditures.

The delayed draw loan bears interest at a fixed rate of 5.02%, plus an interest rate premium of 1.5% until the loan is fully drawn, which must occur within the 18 month draw period. After the earlier of the 18 month draw period or the loan being fully drawn, the interest rate premium may be adjusted quarterly from 0.00% to 1.50% based on the leverage ratio of total funded debt to EBITDA of Wood River and Shenandoah. Principal payments of $1.5 million per year begin 24 months from the closing date. Prepayments are prohibited until September 2024. Financial covenants of the delayed draw loan agreement include a minimum loan to value ratio of 50%, a minimum fixed charge coverage ratio of 1.25x commencing on June 30, 2021, a total debt service reserve of six months of future principal and interest payments and a minimum working capital requirement at Green Plains of not less than $0.10 per gallon of nameplate capacity or $95.8 million. The loan is guaranteed by the company and has certain limitations on distributions, dividends or loans to Green Plains by Wood River and Shenandoah unless immediately after giving effect to such action, there will not exist any event of default.

The company also has small equipment financing loans, finance leases on equipment or facilities, and other forms of debt financing.

Partnership Segment

Green Plains Partners has a term loan to fund working capital, capital expenditures and other general partnership purposes. On July 20, 2021, the prior credit facility was amended decreasing the total amount available to $60.0 million, extending the maturity from December 31, 2021 to July 20, 2026, and converting the credit facility to a term loan. Under the terms of the amended agreement, BlackRock purchased the outstanding $50.0 million balance of the prior credit facility from the previous lenders. Interest on the amended term loan is based on 3-month LIBOR plus 8.00%, with a 0% LIBOR floor. Interest is payable on the 15th day of each March, June, September and December during the term with the first interest payment being September 15, 2021. The amended term loan does not require any principal payments; however, the partnership has the option to prepay $1.5 million per quarter beginning twelve months after the closing date.

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During the nine months ended September 30, 2021, prior to the amendment, the partnership made principal payments of $50.0 million on the prior credit facility, including $19.5 million of scheduled repayments, $27.5 million related to the sale of the storage assets located adjacent to the Ord, Nebraska ethanol plant and a $3.0 million prepayment made with excess cash.

The partnership’s obligations under the term loan are secured by a first priority lien on (i) the equity interests of the partnership’s present and future subsidiaries, (ii) all of the partnership’s present and future personal property, such as investment property, general intangibles and contract rights, including rights under any agreements with Green Plains Trade, (iii) all proceeds and products of the equity interests of the partnership’s present and future subsidiaries and its personal property and (iv) substantially all of the partnership’s real property and material leases of real property. The terms impose affirmative and negative covenants, including restrictions on the partnership’s ability to incur additional debt, acquire and sell assets, create liens, invest capital, pay distributions and materially amend the partnership’s commercial agreements with Green Plains Trade. The term loan also requires the partnership to maintain a maximum consolidated leverage ratio and a minimum consolidated debt service coverage ratio, each of which is calculated on a pro forma basis with respect to acquisitions and divestitures occurring during the applicable period. The maximum consolidated leverage ratio required, as of the end of any fiscal quarter, is no more than 2.50x. The minimum debt service coverage ratio required, as of the end of any fiscal quarter, is no less 1.10x. The consolidated leverage ratio is calculated by dividing total funded indebtedness by the sum of the four preceding fiscal quarters’ consolidated EBITDA. The consolidated debt service coverage ratio is calculated by taking the sum of the four preceding fiscal quarters’ consolidated EBITDA minus income taxes and consolidated capital expenditures for such period divided by the sum of the four preceding fiscal quarters’ consolidated interest charges plus consolidated scheduled funded debt payments for such period.

Under the amended terms of the loan, the partnership has no restrictions on the amount of quarterly distribution payments, so long as (i) no default has occurred and is continuing, or would result from payment of the distribution, and (ii) the partnership and its subsidiaries are in compliance with its financial covenants and remain in compliance after payment of the distribution. The term loan is not guaranteed by the company.

Covenant Compliance

The company was in compliance with its debt covenants as of September 30, 2021.

Restricted Net Assets

At September 30, 2021, there were approximately $174.4 million of net assets at the company’s subsidiaries that could not 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.

9. STOCK-BASED COMPENSATION

The company has an equity incentive plan which reserved a total of 5.7 million shares of common stock for issuance pursuant to the plan. The plan provides for shares, including options to purchase shares of common stock, stock appreciation rights tied to the value of common stock, restricted stock, restricted and deferred stock unit awards and performance share awards to eligible employees, non-employee directors and consultants. The company measures stock-based compensation at fair value on the grant date, with no adjustments for estimated forfeitures. The company records noncash compensation expense related to equity awards in its consolidated financial statements over the requisite period on a straight-line basis.

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Restricted Stock Awards and Deferred Stock Units

The non-vested stock award and deferred stock unit activity for the nine months ended September 30, 2021, is as follows:

	Non-Vested ‎ Shares and ‎ Deferred Stock ‎Units	Weighted- ‎Average Grant- ‎Date Fair Value		Weighted-Average ‎ Remaining ‎ Vesting Term ‎(in years)
Non-Vested at December 31, 2020	1,028,739	$	9.15
Granted	353,181		27.27
Forfeited	(115,896)		14.63
Vested	(474,432)		12.23
Non-Vested at September 30, 2021	791,592	$	14.59	2.0

Performance Shares

On February 18, 2021 and March 18, 2020, the board of directors granted performance shares to be awarded in the form of common stock to certain participants of the plan. These performance shares vest based on the level of achievement of certain performance goals, including the incremental value achieved from the company’s high-protein initiatives, annual production levels and return on investment (ROI). Performance shares granted in 2021 and 2020 do not contain market-based factors requiring a Monte Carlo valuation model. The performance shares were granted at a target of 100%, but each performance share will reduce or increase depending on results for the performance period. If the company achieves the maximum performance goals, the maximum amount of shares available to be issued pursuant to the 2021 and 2020 awards are 936,141 performance shares which represents approximately 271% of the 345,414 performance shares which remain outstanding. The actual number of performance shares that will ultimately vest is based on the actual performance targets achieved at the end of the performance period.

On February 19, 2019, and March 19, 2018, the board of directors granted performance shares to be awarded in the form of common stock to certain participants of the plan. These performance shares vest based on the company’s average return on net assets (RONA) and the company’s total shareholder return (TSR), as further described herein. The performance shares vest on the third anniversary of the grant, if the RONA and TSR criteria are achieved and the participant is then employed by the company. Fifty percent of the performance shares vest based upon the company’s ability to achieve a predetermined RONA during the three year performance period. The remaining fifty percent of the performance shares vest based upon the company’s total TSR during the three year performance period relative to that of the company’s performance peer group.

The performance shares were granted at a target of 100%, but each performance share will reduce or increase depending on results for the performance period for the company's RONA, and the company’s TSR relative to that of the performance peer group. On March 19, 2021, based on criteria discussed above, the 2018 performance shares vested at a target of 75%. If the company’s RONA and TSR achieve the maximum goals, the maximum amount of shares available to be issued pursuant to the 2019 awards are 224,900 performance shares or 150% of the 149,933 performance shares which remain outstanding. The actual number of performance shares that will ultimately vest is based on the actual percentile ranking of the company’s RONA, and the company’s TSR compared to the peer performance at the end of the performance period.

For performance shares which include market-based factors, the company uses the Monte Carlo valuation model to estimate the fair value of the performance shares on the date of the grant. The weighted average assumptions used by the company in applying the Monte Carlo valuation model for performance share grants and related valuation are illustrated in the following table:

FY 2019 Performance Awards
Risk-free interest rate		2.45	%
Dividend yield		3.13	%
Expected volatility		41.69	%
Monte Carlo valuation		99.62	%
Closing stock price on the date of grant	$	15.34

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The non-vested performance share award activity for the nine months ended September 30, 2021, is as follows:

	Performance ‎Shares	Weighted- ‎Average Grant- ‎Date Fair Value		Weighted-Average ‎Remaining ‎Vesting Term ‎(in years)
Non-Vested at December 31, 2020	517,969	$	10.82
Granted	183,316		26.41
Forfeited	(118,023)		15.83
Vested	(87,915)		17.68
Non-Vested at September 30, 2021	495,347	$	14.18	2.2

Green Plains Partners

Green Plains Partners has a long-term incentive plan (LTIP) intended to promote the interests of the partnership, its general partner and affiliates by providing unit-based incentive compensation awards to employees, consultants and directors to encourage superior performance. The LTIP reserves 2,500,000 common limited partner units for issuance in the form of options, restricted units, phantom units, distribution equivalent rights, substitute awards, unit appreciation rights, unit awards, profit interest units or other unit-based awards. The partnership measures unit-based compensation at fair value on the grant date, with no adjustments for estimated forfeitures. The partnership records noncash compensation expense related to the awards over the requisite service period on a straight-line basis.

The unit-based awards activity for the nine months ended September 30, 2021, is as follows:

	Non-Vested ‎ Shares and ‎ Deferred Stock ‎Units	Weighted- ‎Average Grant- ‎Date Fair Value		Weighted-Average ‎ Remaining ‎ Vesting Term ‎(in years)
Non-Vested at December 31, 2020	47,620	$	6.72
Granted	25,976		12.32
Forfeited	(6,494)		12.32
Vested	(47,620)		6.72
Non-Vested at September 30, 2021	19,482	$	12.32	0.8

Stock-Based and Unit Based Compensation Expense

Compensation costs for stock-based and unit-based payment plans were $2.0 million and $4.0 million for the three and nine months ended September 30, 2021, respectively, and $2.1 million and $5.7 million for the three and nine months ended September 30, 2020, respectively. At September 30, 2021, there was $11.5 million of unrecognized compensation costs from stock-based and unit-based compensation related to non-vested awards. This compensation is expected to be recognized over a weighted-average period of approximately 2.1 years. The potential tax benefit related to stock-based payment is approximately 23.9% of these expenses.

10. EARNINGS PER SHARE

Basic earnings per share, or EPS, is calculated by dividing net income available to common stockholders by the weighted average number of common shares outstanding during the period.

The company computed diluted EPS by dividing net income on an if-converted basis, adjusted to add back net interest expense related to the convertible debt instruments, by the weighted average number of common shares outstanding during the period, adjusted to include the shares that would be issued if the convertible debt instruments were converted to common shares and the effect of any outstanding dilutive securities.

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The basic and diluted EPS are calculated as follows (in thousands, except per share amounts):

	Three Months Ended ‎September 30,				Nine Months Ended ‎September 30,
	2021		2020		2021		2020
EPS - basic and diluted:
Net loss attributable to Green Plains	$	(59,622)	$	(34,486)	$	(56,424)	$	(59,145)
Weighted average shares outstanding - basic and diluted		50,482		34,629		44,581		34,632
EPS - basic and diluted:	$	(1.18)	$	(1.00)	$	(1.27)	$	(1.71)
Anti-dilutive weighted-average convertible debt, warrants and stock-based compensation		14,055		14,187		12,458		14,059

11. STOCKHOLDERS’ EQUITY

Early Adoption of ASC 470-20

On January 1, 2021, the company early adopted the amended guidance in ASC 470-20, using the modified retrospective method of transition. The adoption of this guidance resulted in a $49.5 million decrease in additional paid-in capital, an $11.4 million increase in retained earnings and a $38.1 million increase in long-term debt, which included a $39.4 million increase in debt principal offset by a $1.3 million increase in debt issuance costs, resulting from amounts previously bifurcated to equity being reclassified to debt.

Upon adoption of amended guidance in ASC 470-20, the company reversed the remaining deferred tax liability of $9.2 million associated to the equity portion of previously issued convertible debt. As the company had recorded a full valuation allowance against its deferred tax assets, the reversal of the $9.2 million deferred tax liability would require an increase to the existing valuation allowance by the same amount, which would normally be recorded through current income tax expense. However, because the change in the deferred tax liability is directly linked to the adoption of ASC 470-20, which is accounted for as a cumulative effect adjustment, the required increase to the valuation allowance is recorded as part of the cumulative adjustment to stockholders’ equity and has no effect on the income statement.

Public Offerings of Common Stock

On March 1, 2021, the company completed an offering of 8,751,500 shares of our common stock, par value $0.001 per share, in a public offering at a price of $23.00 per share (the “March Common Stock Offering”). The March Common Stock Offering resulted in net proceeds of $191.1 million, after deducting underwriting discounts and commissions and the company’s offering expenses.

On August 9, 2021, the company completed an offering of 5,462,500 shares of our common stock, par value $0.001 per share, in a public offering at a price of $32.00 per share (the “August Common Stock Offering”). The August Common Stock Offering resulted in net proceeds of $164.9 million, after deducting underwriting discounts and commissions and the company’s offering expenses.

Warrants

During the three months ended March 31, 2021, in connection with certain agreements, the company issued warrants to purchase shares of its common stock. The company measures the fair value of the warrants using the Black-Scholes option pricing model as of the issuance date. Exercisable warrants are equity based and recorded as a reduction in additional paid-in capital.

The company has reserved 2,550,000 shares of common stock for the exercise of warrants to non-employees, of which 2,275,000 are exercisable. The remaining 275,000 warrants are contingent upon certain earn-out provisions, treated as liability based awards, and valued quarterly using the company’s stock price. These warrants could potentially dilute basic earnings per share in future periods. The exercise price of the warrants is $22.00 and expiration dates are December 8, 2025 for 275,000 warrants, February 9, 2026 for 275,000 warrants and April 28, 2026 for 2,000,000 warrants.

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Convertible Note Exchange

On May 18, 2021, the company closed on a privately negotiated exchange agreement with certain noteholders of the company’s 4.00% notes, pursuant to which the noteholders agreed to exchange $51.0 million in aggregate principal for 3,568,705 shares of the company’s common stock at an implied price of $26.80.

Components of stockholders’ equity for the three and nine months ended September 30, 2021 and 2020 are as follows (in thousands):

													Total
				Additional		Retained		Accum. Other					Green Plains		Non-		Total
	Common Stock			Paid-in		Earnings		Comp. Income		Treasury Stock			Stockholders'		Controlling		Stockholders'
	Shares	Amount		Capital		(Deficit)		(Loss)		Shares	Amount		Equity		Interests		Equity
Balance, December 31, 2020	47,471	$	47	$	740,889	$	39,375	$	(2,172)	11,813	$	(131,287)	$	646,852	$	129,812	$	776,664
Impact of ASC 470-20 adoption (1)	-		-		(49,496)		11,418		-	-		-		(38,078)		-		(38,078)
Balance, January 1, 2021	47,471		47		691,393		50,793		(2,172)	11,813		(131,287)		608,774		129,812		738,586
Net income (loss)	-		-		-		(6,545)		-	-		-		(6,545)		4,566		(1,979)
Distributions declared	-		-		-		-		-	-		-		-		(1,395)		(1,395)
Other comprehensive income (loss) before reclassification	-		-		-		-		(4,849)	-		-		(4,849)		-		(4,849)
Amounts reclassified from accumulated other comprehensive income (loss)	-		-		-		-		(1,377)	-		-		(1,377)		-		(1,377)
Other comprehensive income (loss), net of tax	-		-		-		-		(6,226)	-		-		(6,226)		-		(6,226)
Investment in subsidiary	-		-		-		-		-	-		-		-		3,330		3,330
Issuance of warrants	-		-		3,431		-		-	-		-		3,431		(3,431)		-
Issuance of common stock for cash at $23.00 per share, net of fees	8,752		9		191,125		-		-	-		-		191,134		-		191,134
Stock-based compensation	230		-		(3,000)		-		-	-		-		(3,000)		79		(2,921)
Balance, March 31, 2021	56,453		56		882,949		44,248		(8,398)	11,813		(131,287)		787,568		132,961		920,529
Net income (loss)	-		-		-		9,743		-	-		-		9,743		6,374		16,117
Distributions declared	-		-		-		-		-	-		-		-		(1,395)		(1,395)
Other comprehensive income (loss) before reclassification	-		-		-		-		5,131	-		-		5,131		-		5,131
Amounts reclassified from accumulated other comprehensive income (loss)	-		-		-		-		3,961	-		-		3,961		-		3,961
Other comprehensive income (loss), net of tax	-		-		-		-		9,092	-		-		9,092		-		9,092
Exchange of 4.00% convertible notes due 2024	-		-		17,679		-		-	(3,569)		39,661		57,340		-		57,340
Investment in subsidiary	-		-		-		-		-	-		-		-		3,139		3,139
Stock-based compensation	(20)		4		324		-		-	-		-		328		80		408
Balance, June 30, 2021	56,433		60		900,952		53,991		694	8,244		(91,626)		864,071		141,159		1,005,230
Net income (loss)	-		-		-		(59,622)		-	-		-		(59,622)		5,211		(54,411)
Distributions declared	-		-		-		-		-	-		-		-		(1,397)		(1,397)
Other comprehensive income (loss) before reclassification	-		-		-		-		538	-		-		538		-		538
Amounts reclassified from accumulated other comprehensive income (loss)	-		-		-		-		(194)	-		-		(194)		-		(194)
Other comprehensive income (loss), net of tax	-		-		-		-		344	-		-		344		-		344
Investment in subsidiary	-		-		-		-		-	-		-		-		1,156		1,156
Issuance of common stock for cash at $32.00 per share, net of fees	5,463		5		164,872		-		-	-		-		164,877		-		164,877
Stock-based compensation	(57)		-		1,759		-		-	-		-		1,759		60		1,819
Balance, September 30, 2021	61,839	$	65	$	1,067,583	$	(5,631)	$	1,038	8,244	$	(91,626)	$	971,429	$	146,189	$	1,117,618

(1)See Note 1 – Recent Accounting Pronouncements and Note 8 – Debt for discussion on adoption of ASC 470-20.

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													Total
				Additional				Accum. Other					Green Plains		Non-		Total
	Common Stock			Paid-in		Retained		Comp. Income		Treasury Stock			Stockholders'		Controlling		Stockholders'
	Shares	Amount		Capital		Earnings		(Loss)		Shares	Amount		Equity		Interests		Equity
Balance, January 1, 2020	46,964	$	47	$	734,580	$	148,150	$	(11,064)	10,932	$	(119,808)	$	751,905	$	113,381	$	865,286
Net income (loss)	-		-		-		(16,445)		-	-		-		(16,445)		6,098		(10,347)
Distributions declared	-		-		-		-		-	-		-		-		(5,498)		(5,498)
Other comprehensive income (loss) before reclassification	-		-		-		-		4,532	-		-		4,532		-		4,532
Amounts reclassified from accumulated other comprehensive income (loss)	-		-		-		-		(4,485)	-		-		(4,485)		-		(4,485)
Other comprehensive income (loss), net of tax	-		-		-		-		47	-		-		47		-		47
Share of equity method investees other comprehensive income (loss) arising during the period, net of tax	-		-		-		-		41,956	-		-		41,956		-		41,956
Repurchase of common stock	-		-		-		-		-	881		(11,479)		(11,479)		-		(11,479)
Stock-based compensation	343		-		36		-		-	-		-		36		79		115
Balance, March 31, 2020	47,307		47		734,616		131,705		30,939	11,813		(131,287)		766,020		114,060		880,080
Net income (loss)	-		-		-		(8,214)		-	-		-		(8,214)		2,740		(5,474)
Distributions declared	-		-		-		-		-	-		-		-		(1,389)		(1,389)
Other comprehensive income (loss) before reclassification	-		-		-		-		(1,333)	-		-		(1,333)		-		(1,333)
Amounts reclassified from accumulated other comprehensive income (loss)	-		-		-		-		(7)	-		-		(7)		-		(7)
Other comprehensive income (loss), net of tax	-		-		-		-		(1,340)	-		-		(1,340)		-		(1,340)
Share of equity method investees other comprehensive income (loss) arising during the period, net of tax	-		-		-		-		(16,759)	-		-		(16,759)		-		(16,759)
Stock-based compensation	160		-		2,072		-		-	-		-		2,072		80		2,152
Balance, June 30, 2020	47,467		47		736,688		123,491		12,840	11,813		(131,287)		741,779		115,491		857,270
Net income (loss)	-		-		-		(34,486)		-	-		-		(34,486)		3,753		(30,733)
Distributions declared	-		-		-		-		-	-		-		-		(1,394)		(1,394)
Other comprehensive income (loss) before reclassification	-		-		-		-		(2,696)	-		-		(2,696)		-		(2,696)
Amounts reclassified from accumulated other comprehensive income (loss)	-		-		-		-		-	-		-		-		-		-
Other comprehensive income (loss), net of tax	-		-		-		-		(2,696)	-		-		(2,696)		-		(2,696)
Share of equity method investees other comprehensive income (loss) arising during the period, net of tax	-		-		-		-		(21,057)	-		-		(21,057)		-		(21,057)
Stock-based compensation	-		-		2,086		-		-	-		-		2,086		79		2,165
Balance, September 30, 2020	47,467	$	47	$	738,774	$	89,005	$	(10,913)	11,813	$	(131,287)	$	685,626	$	117,929	$	803,555

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Amounts reclassified from accumulated other comprehensive income are as follows (in thousands):

	Three Months Ended ‎September 30,				Nine Months Ended ‎September 30,				Statements of ‎Operations
	2021		2020		2021		2020		Classification
Gains (losses) on cash flow hedges:
Commodity derivatives	$	(691)	$	-	$	(39,571)	$	8,824	(1)
Commodity derivatives		947		-		36,431		(2,901)	(2)
Total gains on cash flow hedges		256		-		(3,140)		5,923	(3)
Income tax benefit (expense)		(62)		-		750		(1,431)	(4)
Amounts reclassified from accumulated other comprehensive income (loss)	$	194	$	-	$	(2,390)	$	4,492

(1)Revenues

(2)Costs of goods sold

(3)Loss before income taxes and income from equity method investees

(4)Income tax benefit (expense)

12. INCOME TAXES

The company records actual income tax expense or benefit during interim periods rather than on an annual effective tax rate method. Certain items are given discrete period treatment and the tax effect of those items are reported in full in the relevant interim period. Green Plains Partners is a limited partnership, which is treated as a flow-through entity for federal income tax purposes and is not subject to federal income taxes. As a result, the consolidated financial statements do not reflect income taxes on pre-tax income or loss attributable to the noncontrolling interest in the partnership.

The CARES Act was signed into law on March 27, 2020. The CARES Act includes several significant business tax provisions, including elimination of the taxable limit for certain net operating losses (“NOL”), allowing businesses to carry back NOLs arising in 2018, 2019 and 2020 to the five prior tax years, accelerating refunds of previously generated corporate AMT credits, and loosening the business interest limitation under §163(j) from 30% to 50%. The CARES Act also contains an employee retention credit to encourage employers to maintain headcounts even if employees cannot report to work because of issues related to the COVID-19. In the first quarter of 2020, the company recorded an income tax benefit related to the expected NOL carry back claim of $28.4 million, which was an estimate based on the amount of NOL rated to the 2019 year-end tax provision. No additional tax benefit was recorded related to the CARES Act during the nine months ended September 30, 2021.

The company recorded income tax expense of $7 thousand and income tax benefit of $2.9 million for the three and nine months ended September 30, 2021, compared with income tax expense of $7.3 million and income tax benefit of $48.5 million for the same periods in 2020. The decrease in income tax expense recorded for the three months ended September 30, 2021 was primarily due to a decrease in pretax book income for the period offset by recording a valuation allowance against the tax net operating loss (NOL) generated in the period. The decrease in the amount of tax benefit recorded for the nine months ended September 30, 2021 compared to the same period in 2020 was primarily due to the tax benefit recognized in 2020 associated with the carry back of the tax NOL generated in 2019 to the 2014 tax year under the newly enacted CARES Act. The amount of unrecognized tax benefits for uncertain tax positions was $51.4 million as of September 30, 2021 and December 31, 2020.

The effective tax rate can be affected by variances in the estimates and amounts of taxable income among the various states, entities and activity types, realization of tax credits, adjustments from resolution of tax matters under review, valuation allowances and the company’s assessment of its liability for uncertain tax positions.

Upon adoption of amended guidance in ASC 470-20, during the first quarter of 2021, the company reversed the remaining deferred tax liability of $9.2 million associated to the equity portion of previously issued convertible debt. As the company had recorded a full valuation allowance against its deferred tax assets, the reversal of the $9.2 million deferred tax liability would require an increase to the existing valuation allowance by the same amount which would normally be recorded through current income tax expense. However, as the change in the deferred tax liability is directly linked to the adoption of ASC 470-20, which is accounted for as a cumulative effect adjustment, the required increase to the valuation allowance is recorded as part of the cumulative adjustment to stockholders’ equity and has no effect on the consolidated statements of operations.

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13. COMMITMENTS AND CONTINGENCIES

Lease Expense

The company leases certain facilities, parcels of land, and equipment, with remaining terms ranging from less than one year to approximately 16 years. The land and facility leases include renewal options. The renewal options are included in the lease term only for those sites or locations that are reasonably certain to be renewed. Equipment renewals are not considered reasonably certain to be exercised as they typically renew with significantly different underlying terms.

The company may sublease certain of its railcars to third parties on a short-term basis. The subleases are classified as operating leases, with the associated sublease income being recognized on a straight-line basis over the lease term.

The components of lease expense are as follows (in thousands):

	Three Months Ended ‎September 30,				Nine Months Ended ‎September 30,
	2021		2020		2021		2020
Lease expense
Operating lease expense	$	4,803	$	5,232	$	14,645	$	15,432
Variable lease expense (1)		301		530		892		1,429
Total lease expense	$	5,104	$	5,762	$	15,537	$	16,861

(1)Represents amounts incurred in excess of the minimum payments required for a certain building lease and for the handling and unloading of railcars for a certain land lease, offset by railcar lease abatements provided by the lessor when railcars are out of service during periods of maintenance or upgrade.

Supplemental cash flow information related to operating leases is as follows (in thousands):

	Three Months Ended ‎September 30,				Nine Months Ended ‎September 30,
	2021		2020		2021		2020
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	4,706	$	5,136	$	14,352	$	15,004
Right-of-use assets obtained in exchange for lease obligations:
Operating leases		7,162		11,053		17,934		17,932
Right-of-use assets and lease obligations derecognized due to lease modifications:
Operating leases		1,838		12		1,889		12

Supplemental balance sheet information related to operating leases is as follows:

	September 30, 2021		December 31, 2020
Weighted average remaining lease term		5.7 years		6.2 years
Weighted average discount rate		4.17%		4.55%

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Aggregate minimum lease payments under the operating lease agreements for the remainder of 2021 and in future years are as follows (in thousands):

Year Ending December 31,	Amount
2021	$	5,432
2022		19,026
2023		16,197
2024		13,797
2025		9,508
Thereafter		17,127
Total		81,087
Less: Present value discount		(11,271)
Lease liabilities	$	69,816

The company has an additional railcar operating lease that will commence in the fourth quarter of 2021, with estimated future minimum lease commitments of approximately $0.7 million and a lease term of three years. The undiscounted amounts are not included in the tables above.

Lease Revenue

As described in Note 2 – Revenue, the majority of the partnership’s segment revenue is generated through their storage and throughput services and rail transportation services agreements with Green Plains Trade and are accounted for as lease revenue. Leasing revenues do not represent revenues recognized from contracts with customers under ASC 606, and are accounted for under ASC 842, Leases. Lease revenue associated with agreements with Green Plains Trade is eliminated upon consolidation. The remaining lease revenue is not material to the company. Refer to Note 2 – Revenue for further discussion on lease revenue.

Commodities

As of September 30, 2021, the company had contracted future purchases of grain, corn oil, natural gas, ethanol and distillers grains, valued at approximately $372.7 million.

Legal

The company is currently involved in litigation that has arisen during the ordinary course of business, but does not believe any pending litigation will have a material adverse effect on its financial position, results of operations or cash flows.

14. RELATED PARTY TRANSACTIONS

Green Plains Cattle Company LLC

The company engaged in certain related party transactions with GPCC, which was considered a related party until the fourth quarter of 2020 at which time the company’s remaining 50% interest was sold. The company provided a variety of shared services to GPCC, including accounting and finance, payroll and human resources, information technology, legal, communications and treasury activities. The company reduced selling, general and administrative expenses by $0.4 million and $1.2 million related to shared services provided for the three and nine months ended September 30, 2020.

Green Plains Trade Group, a subsidiary of the company, enters into certain sale contracts with GPCC during the normal course of business. Revenues were $2.2 million and $8.2 million for the three and nine months ended September 30, 2020.

Mr. Ejnar Knudsen, a member of the company’s board of directors, has an indirect ownership interest in GPCC of 0.0736% by reason of his ownership in TGAM Agribusiness Fund LP.  Based on the purchase price, the value of that ownership interest is approximately $0.1 million. Mr. Knudsen also is the CEO and partial owner of AGR Partners LLC, which provides investment advisory services to TGAM Agribusiness Fund LP pursuant to a sub-advisory agreement between AGR Partners LLC and Nuveen Alternative Advisors LLC, which is the investment manager for TGAM Agribusiness Fund LP and receives usual and customary advisory fees.

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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 we believe is relevant to understand our consolidated financial condition and results of operations. This discussion should be read in conjunction with the consolidated financial statements and notes to the consolidated financial statements contained in this report together with our annual report on Form 10-K for the year ended December 31, 2020.

Cautionary Information Regarding Forward-Looking Statements

Forward-looking statements are made in accordance with safe harbor provisions of the Private Securities Litigation Reform Act of 1995. These statements are based on current expectations that involve a number of risks and uncertainties and do not relate strictly to historical or current facts, but rather to plans and objectives for future operations. These statements may be identified by words such as “anticipate,” “believe,” “continue,” “estimate,” “expect,” “intend,” “outlook,” “plan,” “predict,” “may,” “could,” “should,” “will” and similar expressions, as well as statements regarding future operating or financial performance or guidance, business strategy, environment, key trends and benefits of actual or planned acquisitions.

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, 2020, Part II, Item 1A – Risk Factors in this report, or incorporated by reference. Specifically, we may experience fluctuations in future operating results due to a number of economic conditions, including: disruption caused by health epidemics, such as the COVID-19 outbreak; competition in the ethanol industry and other industries in which we operate; commodity market risks, including those that may result from weather conditions; financial market risks; counterparty risks; risks associated with changes to government policy or regulation, including changes to tax laws; risks related to acquisition and disposition activities and achieving anticipated results; risks associated with merchant trading; risks related to our equity method investees and other factors detailed in reports filed with the SEC. Additional risks related to Green Plains Partners LP include compliance with commercial contractual obligations, potential tax consequences related to our investment in the partnership and risks disclosed in the partnership’s SEC filings associated with the operation of the partnership as a separate, publicly traded entity.

We believe our expectations regarding future events are based on reasonable assumptions; however, these assumptions may not be accurate or account for all risks and uncertainties. Consequently, forward-looking statements are not guaranteed. Actual results may vary materially from those expressed or implied in our forward-looking statements. In addition, we are not obligated and do not intend to update our forward-looking statements as a result of new information unless it is required by applicable securities laws. We caution investors not to place undue reliance on forward-looking statements, which represent management’s views as of the date of this report or documents incorporated by reference.

Overview

Green Plains is an Iowa corporation founded in June 2004 as a producer of low carbon fuels and has grown to be one of the leading corn processors in the world. We continue the transition from a commodity-processing business to a value-add agricultural technology company focusing on creating diverse, non-cyclical, higher margin products. In addition, we are currently undergoing a number of project initiatives to improve margins. Through our Project 24 initiative, we anticipate reductions in operating expense per gallon across our non-ICM plants and with our Total Transformation Plan to a value-add agricultural technology company, we believe we can further increase margin per gallon by producing additional value-added ingredients and expanding corn oil yields.

We are focused on generating stable operating margins through our business segments and risk management strategy. We own and operate assets throughout the ethanol value chain: upstream, with grain handling and storage; through our ethanol production facilities; and downstream, with marketing and distribution services to mitigate commodity price volatility. Our other businesses leverage our supply chain, production platform and expertise.

We operate within four business segments: (1) ethanol production, which includes the production of ethanol, including industrial-grade alcohol, distillers grains, Ultra-High Protein and corn oil, (2) agribusiness and energy services, which includes grain handling and storage, and commodity marketing for company-produced and third-party ethanol, distillers grains, corn oil, natural gas and other commodities, (3) food and ingredients, and (4) partnership, which includes fuel storage and transportation services. The food and ingredients segment had no activity during the three and nine months ended September 30, 2021 and 2020.

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Our ethanol production segment operates 11 facilities across the Midwest that process annually renewable crops to produce a growing number of value-added ingredients, including low-carbon biofuels, specialty alcohols, Ultra-High Protein, distillers grains and renewable corn oil. We are executing on our Total Transformation Plan by utilizing Fluid Quip Technologies’ MSC™ protein technology to expand our ability to produce value-added ingredients at each of our locations while expanding corn oil yields.

As part of our transformation to a value-add agricultural technology company, we completed our first MSC™ Ultra-High Protein installation our Shenandoah biorefinery during the first quarter of 2020. Our Wood River plant began operations in October 2021. Three additional locations are slated to begin operating by mid-2022, and installation at our remaining biorefineries is expected over the course of the next several years. Through our value-added ingredients initiative, we expect to produce Ultra-High Protein, a feed ingredient with protein concentrations of 50% or greater, increase production of corn oil as well produce other higher value products, such as post-MSC distillers grains.

Our agribusiness and energy segment procures grain and natural gas for our ethanol production segment as well as manages risk for it. It also markets finished goods for our ethanol production segment as well as third parties, manages product inventory and customer invoicing, and optimizes physical and financial flows for many of our products. Consisting of fee based, marketing and origination entities, it originates corn directly from local farmers and stores it onsite for later utilization in our biorefinery plants and later handles the sale of valued-added ingredients to final destinations.

Our partnership segment represents our consolidated ownership of Green Plains Partners LP, a publicly-traded, master limited partnership. Green Plains Partners LP is our primary downstream logistics provider, storing and delivering the ethanol we produce. We own a 48.9% limited partner interest, a 2.0% general partner interest and all of the partnership’s incentive distribution rights. The public owns the remaining 49.1% limited partner interest. The partnership is consolidated in our financial statements. It owns storage terminals at each of our 11 plant locations as well as other locations and primarily provides biofuel storage for our ethanol production segment. Through its railcar and trucking fleet, it provides transportation and logistics services to efficiently deliver low-carbon fuels produced by our ethanol production segment to their end destinations.

In August 2021, we announced a turnkey solution for the installation of Fluid Quip Technologies’ MSC™ protein technology for third party plants with Tharaldson Ethanol, a 175 million-gallon facility in North Dakota.

In February and April 2021, as part of our carbon reduction strategy, we have committed our Nebraska, Iowa and Minnesota plants to the Summit Carbon Solutions Midwest Carbon Express project to capture and store carbon dioxide produced through the fermentation process. In total, eight of our biorefineries have entered into long-term carbon offtake agreements, which will lower greenhouse gas emissions through the capturing and storing of carbon dioxide at each of the biorefineries, significantly lowering their carbon intensity. This project is expected to be completed in 2024.

In December 2020, we completed the purchase of a majority interest in Fluid Quip Technologies, LLC. The acquisition capitalizes on the core strengths of each company to develop and implement proven, value-added agriculture, food and industrial biotechnology systems and rapidly expand installation and production of Ultra-High Protein across Green Plains facilities, as well as offer these technologies to partnering biofuel facilities through our turnkey initiative.

Our profitability is highly dependent on commodity prices, particularly for ethanol, industrial alcohol, distillers grains, corn oil, soybean meal, corn, and natural gas. Since market price fluctuations of these commodities are not always correlated, our operations may be unprofitable at times. We use a variety of risk management tools and hedging strategies to monitor price risk exposure at our ethanol plants and lock in favorable margins or reduce production when margins are compressed.

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Recent Developments

Public Offering of Common Stock

On August 9, 2021, we completed the public offering of 5,462,500 shares of our common stock, par value $0.001 per share, at a public offering price of $32.00 per share (the “August Common Stock Offering”). The August Common Stock Offering resulted in net proceeds of approximately $164.9 million after deducting underwriting discounts and commissions and the company’s estimated offering expenses. We intend to use the proceeds from the August Common Stock Offering for growth investments to further accelerate our downstream development opportunities. For additional information related to the August Common Stock Offering, see Note 11 – Stockholders’ Equity included as part of the notes to consolidated financial statements.

Amendment to Partnership Credit Agreement

On July 20, 2021, the partnership entered into an Amended and Restated Credit Agreement to its existing credit facility with funds and account managed by BlackRock and TMI Trust Company as administrative agent.

Under the terms of the agreement, BlackRock purchased the outstanding balance of the previous credit facility from the previous lenders and the credit facility was modified to a term loan. The term loan matures on July 20, 2026, and has a principal balance of $60.0 million. Interest on the term loan is based on 3-month LIBOR plus 8.00%, with a 0% LIBOR floor. Interest is payable on the 15th day of each March, June, September and December, with the first interest payment being September 15, 2021. The term loan does not require any principal payments; however, we have the option to prepay $1.5 million per quarter beginning twelve months after the closing date. Financial covenants include a maximum consolidated leverage ratio of 2.50x and a minimum consolidated debt service coverage ratio of 1.10x. The Amended Credit Facility continues to be secured by substantially all of the assets of the partnership.

Results of Operations

During the third quarter of 2021, we experienced a weak ethanol margin environment due to historically high physical corn basis levels across our entire platform. We maintained an average utilization rate of approximately 75.0% of capacity, resulting in ethanol production of 181.2 mmg for the third quarter of 2021, compared with 189.2 mmg, or 66.8% of capacity, for the same quarter last year. The increase in the average utilization rate was primarily due to capacity offline in the prior year due to poor margins driven in part by a significant reduction in motor fuel demand as a result of the COVID-19 pandemic, while the decline in overall volumes was primarily due to the sale of Green Plains Ord. Our operating strategy is to reduce operating expenses, energy usage and water consumption through our Project 24 initiative while running at higher utilization rates in order to achieve improved margins. However, in the current environment, we may continue to exercise operational discretion that results in reductions in production. Additionally, we may experience lower run rates due to the construction of various projects. It is possible that production could be below minimum volume commitments in the future, depending on various factors that drive each biorefineries variable contribution margin, including future driving and gasoline demand for the industry. 

U.S. Ethanol Supply and Demand

According to the EIA, domestic ethanol production averaged 1.0 million barrels per day during the third quarter of 2021, which was 6% higher than the 0.92 million barrels per day for the same quarter last year. Refiner and blender input volume increased 9% to 919 thousand barrels per day for the third quarter of 2021, compared with 846 thousand barrels per day for the same quarter last year. Gasoline demand increased 0.7 million barrels per day, or 9%, during the third quarter of 2021 compared to the prior year. U.S. domestic ethanol ending stocks increased by approximately 0.5 million barrels compared to the prior year, or 3%, to 20.2 million barrels during the third quarter of 2021. As of September 30, 2021, according to Prime the Pump, there were approximately 2,504 retail stations selling E15 in 30 states, up from 2,300 at the beginning of the year, and approximately 262 pipeline terminal locations now offering E15 to wholesale customers.

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Global Ethanol Supply and Demand

According to the USDA Foreign Agriculture Service, domestic ethanol exports through August 31, 2021, were approximately 796 mmg, down 10% from 885 mmg for the same period of 2020. Canada was the largest export destination for U.S. ethanol accounting for 28% of domestic ethanol export volume. India, South Korea, China, and Peru accounted for 13%, 13%, 13% and 4%, respectively, of U.S. ethanol exports. We currently estimate that net ethanol exports will be approximately 1.3 billion gallons in 2021, based on historical demand from a variety of countries and certain countries who seek to improve their air quality and eliminate MTBE from their own fuel supplies.

In January 2020, China and the United States struck a “Phase I” trade agreement, which included commitments on agricultural commodity purchases. Ethanol, corn and distillers grains were included as potential purchases in the agreement. China has been purchasing large quantities of corn, which has raised domestic prices of this feedstock for our ethanol production process. In addition, in October 2020, it was announced that China had purchased a shipment of U.S. ethanol for the first time since March 2018. Total ethanol exports to China in 2020 were 31.7 million gallons, and through August 2021 were 100.1 million gallons, according to the USDA Foreign Agriculture Service.

Year-to-date U.S. distillers grains exports through August 31, 2021, were 7.7 million metric tons, or 9.2% higher than the same period last year, according to the USDA Foreign Agriculture Service. Mexico, Vietnam, South Korea, Turkey and Indonesia accounted for approximately 57.8% of total U.S. distillers export volumes.

Legislation and Regulation

We are sensitive to government programs and policies that affect the supply and demand for ethanol and other fuels, which in turn may impact the volume of ethanol and other fuels we handle. Over the years, various bills and amendments have been proposed in the House and Senate, which would eliminate the RFS II entirely, eliminate the corn based ethanol portion of the mandate, and make it more difficult to sell fuel blends with higher levels of ethanol. We believe it is unlikely that any of these bills will become law in the current Congress. In addition, the manner in which the EPA administers the RFS II and related regulations can have a significant impact on the actual amount of ethanol blended into the domestic fuel supply.

Federal mandates and state-level clean fuel programs supporting the use of renewable fuels are a significant driver of ethanol demand in the U.S. Ethanol policies are influenced by concerns for the environment, diversifying the fuel supply, and reducing the country’s dependence on foreign oil. Consumer acceptance of FFVs and higher ethanol blends in non-FFVs may be necessary before ethanol can achieve further growth in U.S. market share. In addition, expansion of clean fuel programs in other states, or a national low carbon fuel standard could increase the demand for ethanol, depending on how it is structured.

Congress first enacted CAFE standards in 1975 to reduce energy consumption by increasing the fuel economy of cars and light trucks. FFVs, which are designed to run on a mixture of fuels, including higher blends of ethanol such as E85, used to receive preferential treatment in the form of CAFE credits. There are approximately 21 million FFVs on the road in the U.S. today, 16 million of which are light duty trucks. FFV credits have been decreasing since 2014 and were completely phased out in 2020. Absent CAFE preferences, auto manufacturers may not be willing to build flexible-fuel vehicles, which has the potential to slow the growth of E85 markets. However, California’s Low Carbon Fuel Standard program (LCFS) has driven growth in E85 usage, and other state/regional LCFS programs have the potential to do the same.

The RFS II sets a floor for biofuels use in the United States. When the RFS II was established in 2010, the required volume of “conventional”, or corn-based, ethanol to be blended with gasoline was to increase each year until it reached 15.0 billion gallons in 2015, which left the EPA to address existing limitations in both supply and demand. As of this filing, the EPA has not released the proposed RVO for 2021 and 2022, although they are expected to propose a joint rule in November of 2021 and finalize by the end of the calendar year.

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According to the RFS II, if mandatory renewable fuel volumes are reduced by at least 20% for two consecutive years, the EPA is required to modify, or reset, statutory volumes through 2022 – the year through which the statutorily prescribed volumes run. While conventional ethanol maintained 15 billion gallons, 2019 was the second consecutive year that the total RVO was more than 20% below the statutory volumes levels. Thus, the EPA was expected to initiate a reset rulemaking, and modify statutory volumes through 2022, and do so based on the same factors they are to use in setting the RVOs post 2022. These factors include environmental impact, domestic energy security, expected production, infrastructure impact, consumer costs, job creation, price of agricultural commodities, food prices, and rural economic development. However, in late 2019, the EPA announced it would not be moving forward with a reset rulemaking in 2020. It is unclear when or if the current EPA will propose a reset rulemaking, though they have stated an intention to propose a post 2022 set rulemaking by the end of 2021.

Under the RFS, RINs and SREs are important tools impacting supply and demand. The EPA assigns individual refiners, blenders, and importers the volume of renewable fuels they are obligated to use in each annual RVO based on their percentage of total domestic transportation fuel sales. Obligated parties use RINs to show compliance with the RFS II mandated volumes. Ethanol producers assign RINs to renewable fuels and the RINs are detached when the renewable fuel is blended with transportation fuel domestically. Market participants can trade the detached RINs in the open market. The market price of detached RINs can affect the price of ethanol in certain markets and can influence purchasing decisions by obligated parties. As it relates to SREs, a small refinery is defined as one that processes fewer than 75,000 barrels of petroleum per day. Small refineries can petition the EPA for a SRE which, if approved, waives their portion of the annual RVO requirements. The EPA, through consultation with the DOE and the USDA, can grant them a full or partial waiver, or deny it outright within 90 days of submittal. The EPA granted significantly more of these waivers for 2016, 2017 and 2018 than they had in the past, totaling 790 mmg of waived requirements for the 2016 compliance year, 1.82 billion gallons for 2017 and 1.43 billion gallons for 2018. In doing so, the EPA effectively reduced the RFS II mandated volumes for those compliance years by those amounts respectively, and as a result, RIN values declined significantly. In the waning days of the Trump administration, the EPA approved three additional SREs, reversing one denial from 2018 and granting two from 2019. A total of 88 SREs were granted under the Trump Administration, totaling 4.3 billion gallons of potential blending demand erased. The EPA, under the current administration, reversed the three SREs issued in the final weeks of the previous administration, and have indicated they will take a different approach to adjudicating SREs than the prior administration.

The One-Pound Waiver that was extended in May 2019 to allow E15 to be sold year-round to all vehicles model year 2001 and newer was challenged in an action filed in Federal District Court for the D.C. Circuit. On July 2, 2021, the Circuit Court vacated the EPA’s rule so the future of summertime, defined as June 1 to September 15, sales of E15 to non-FFVs is uncertain. As of this filing E15 is sold year-round in approximately 30 states. In January 2021, the EPA announced it intended to begin a rulemaking regarding E15 labels and underground storage tank compatibility.

Biofuels groups have filed a lawsuit in the Court of Appeals for the D.C. Circuit, challenging the 2019 RVO rule over the EPA’s failure to address SREs in the rulemaking. This was the first RFS II rulemaking since the expanded use of the exemptions came to light. However, the EPA had declined to cap the number of waivers it grants, and until late 2019, had declined to alter how it accounts for the retroactive waivers in its annual volume calculations. The EPA has a statutory mandate to ensure the volume requirements are met, which is achieved by setting the percentage standards for obligated parties. The EPA’s recent approach accomplished the opposite. Even if all the obligated parties complied with their respective percentage obligations for 2019, the nation’s overall supply of renewable fuel would not meet the total volume requirements set by the EPA. This undermines Congressional intent to increase the consumption of renewable fuels in the domestic transportation fuel supply. Biofuels groups have argued the EPA must therefore adjust its percentage standard calculations to make up for past retroactive waivers and adjust the standards to account for any waivers it reasonably expects to grant in the future.

In 2017, while citing inadequate domestic supply, the D.C. Circuit ruled in favor of biofuel groups against the EPA related to its decision to lower the 2016 volume requirements by 500 mmg. As a result, the Court remanded to the EPA to make up for the 500 mmg. Despite this, in the proposed 2020 RVO rulemaking released in July 2019, the EPA stated it does not intend to make up the 500 mmg as the court directed, citing potential burden on obligated parties. The EPA had, at one point, indicated that it planned to address this court ordered remand in conjunction with the 2021 RVO rulemaking; however that rulemaking has been delayed indefinitely, and whether these gallons will be accounted for is unclear.

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In 2019, in a supplemental rulemaking to the 2020 RVO rule, the EPA changed their approach, and for the first time accounted for the gallons that they anticipate will be waived from the blending requirements due to small refinery exemptions. To accomplish this, they added in the trailing three year average of gallons the DOE recommended be waived, in effect raising the blending volumes across the board in anticipation of waiving the obligations in whole or in part for certain refineries that qualify for the exemptions. Though the EPA has often disregarded the recommendations of the DOE in years past, they stated in the rule their intent to adhere to these recommendations going forward, including granting partial waivers rather than an all or nothing approach.

In January 2020, the U.S. Court of Appeals for the 10^th Circuit ruled on RFA et. al. vs. EPA in favor of biofuels interests, overturning EPA’s granting of refinery exemptions to three refineries on two separate grounds. The Court agreed that, under the Clean Air Act, refineries are eligible for SREs for a given RVO year only if such exemptions are extensions of exemptions granted in previous RVO years. In this case, the three refineries at issue did not qualify for SREs in the year prior to the year that EPA granted them. They were thus ineligible for additional SRE relief because there were no immediately prior SREs to extend. In addition, the Court agreed that the disproportionate economic hardship prong of SRE eligibility should be determined solely by reference to whether compliance with the RFS II creates such hardship, not whether compliance plus other issues create disproportionate economic hardship. The Court thus vacated EPA's grant of SREs for certain years and remanded the grants back to EPA. The refiners appealed for a rehearing which was denied. Two of the refiners appealed the decision to the U.S. Supreme Court and in January 2021, the Supreme Court announced they would hear the case, and oral arguments were held in late April 2021. In February 2021, the EPA indicated that it intends to adhere to the 10^th Circuit ruling. On June 25, 2021, the Supreme Court ruled that the 10^th Circuit’s interpretation of “extension” was too narrow, and vacated that portion of the ruling. As of this filing, it is unclear how this Supreme Court decision may impact the EPA’s handling of SREs.

In light of the 10^th Circuit ruling, a number of refineries applied for “gap year” SREs in an effort to establish a continuous string of relief and to ensure they are able to qualify for SREs going forward. A total of 64 gap year requests were filed with the EPA and reviewed by the DOE. In September 2020, the EPA announced that they were denying 54 of the gap year requests that had been scored and returned by DOE, regardless of how they had been scored.

In October 2019, the White House directed the USDA and EPA to move forward with rulemaking to expand access to higher blends of biofuels. This includes funding for infrastructure, labeling changes and allowing E15 to be sold through E10 infrastructure. The USDA rolled out the Higher Blend Infrastructure Incentive Program in the summer of 2020, providing competitive grants to fuel terminals and retailers for installing equipment for dispensing higher blends of ethanol and biodiesel. Congress is considering legislation that would provide for an additional $1 billion in USDA grants for biofuel infrastructure from 2022 to 2031. In 2020, five Governors and 15 Republican Senators sent letters to the EPA requesting a general waiver from the RFS due to the drop in demand caused by COVID-19 travel restrictions. Since then there have been additional petitions for waivers from the RFS requirements. As of this filing the EPA had indicated only that they are watching the situation closely and reviewing the various requests.

To respond to the COVID-19 health crisis and attempt to offset the subsequent economic damage, Congress passed multiple relief measures, most notably the CARES Act in March 2020, which created and funded multiple programs that have impacted our industry. The USDA was given additional resources for the Commodity Credit Corporation (CCC) and they are using those funds to provide direct payments to farmers, including corn farmers from whom we purchase most of our feedstock for ethanol production. Similar to the trade aid payments made by the USDA over the past two years, this cash injection for farmers could cause them to delay marketing decisions and increase the price we have to pay to purchase corn. The CARES Act also allowed for certain net operating loss carrybacks, which has allowed us to receive certain tax refunds. In December 2020, Congress passed and the President signed into law an annual spending package coupled with another COVID relief bill which included additional funds for the Secretary of Agriculture to distribute to those impacted by the pandemic. The language of the bill specifically includes biofuels producers as eligible for some of this aid, and in March of 2021, the USDA indicated that biofuels would be able to apply for a portion of these funds in a forthcoming rulemaking. On June 15, 2021, the USDA indicated that $700 million would be made available to biofuels producers, and that details for the program would be released within 60 days; however, they have yet to make additional details public.

The CARES Act provided a tax exclusion on the shipment of undenatured ethanol for use in manufacturing hand sanitizer, a key ingredient of which is undenatured ethanol of specific grades. The FDA announced that it is ending, effective December 31, 2021, the expanded guidance, which allowed for more denaturants to be used in ethanol intended for hand sanitizer production, and expanded the grades of ethanol for the duration of the public health crisis.

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The current administration has indicated a desire to dramatically expand electric vehicle (EV) charging stations, and initially proposed $174 billion for EV charging infrastructure, purchase rebates, and other incentives. The bipartisan infrastructure package being considered by Congress includes $15 billion for EV charging infrastructure, and $5 billion for electric busses and ferries. Additionally, Congress is considering expanded EV incentives in a budget reconciliation package, with the goal of installing 500,000 EV charging stations and providing incentives to middle and lower income Americans to purchase EVs, in addition to manufacturing incentives for car makers. The package would offer consumers tax rebates of $7,500 to $12,500 for purchasing EVs, and would invest billions in charging infrastructure. These tax incentives could reduce the overall market for liquid fuels in the surface transportation sector and with it, that of ethanol.

The budget reconciliation package currently being considered by Congress also would extend the $1.00/gallon tax credits for renewable diesel and biodiesel, which use our distillers corn oil as one of their low-carbon feedstocks. The package would also create a $1.25 - $1.75/gallon tax incentive for the production of sustainable aviation fuel, which could possibly utilize our distillers corn oil or our ethanol as a feedstock. The package would also expand tax credits for carbon capture and sequestration (CCS) and extend the time frame for projects to qualify for this credit. The fermentation process by which we produce ethanol releases a nearly pure stream of CO2 which has the potential to be captured and sequestered. The package would also create a technology-neutral clean fuel production tax credit for 2027, but this would not be applicable for fuels that take advantage of the CCS tax credits. The package in its current form also expands the eligibility of Master Limited Partnership tax status to clean energy projects, including CCS and renewable fuels. There can be no assurance, however, these provisions make it into any final legislation.

Government actions abroad can significantly impact the demand for U.S. ethanol. In September 2017, China’s National Development and Reform Commission, the National Energy Agency and 15 other state departments issued a joint plan to expand the use and production of biofuels containing up to 10% ethanol by 2020. China, the number three importer of U.S. ethanol in 2016, imported negligible volumes during 2018 and 2019 due to a 30% tariff on U.S. ethanol, which increased to 70% in early 2018. There is no assurance that China’s joint plan to expand blending to 10% will be carried to fruition, nor that it will lead to increased imports of U.S. ethanol in the near term. Ethanol is included as an agricultural commodity under the “Phase I” agreement with China, wherein they are to purchase upwards of $40 billion in agricultural commodities from the U.S. in both 2020 and 2021. According to the U.S. Department of Agriculture Foreign Agricultural Service, China purchased 32 mmg of U.S. ethanol in 2020 and through August 2021 had imported 100 mmg.

In Brazil, the Secretary of Foreign Trade had issued a tariff rate quota which expired in December of 2020. All U.S. ethanol gallons now face a 20% tariff into Brazil. Exports to Brazil were 200 mmg in 2020. Our exports also face tariffs, rate quotas, countervailing duties, and other hurdles in the European Union, India, Peru, Colombia and elsewhere, which limits the ability to compete in some markets. We believe some countries are using the COVID-19 crisis as justification for raising duties on imports of U.S. ethanol, or blocking our imports entirely.

In June 2017, the Energy Regulatory Commission of Mexico (CRE) approved the use of 10% ethanol blends, which was challenged by multiple lawsuits, of which several were dismissed. The remaining four cases follow one of two tracks: 1) to determine the constitutionality of the CRE regulation, or 2) to determine the benefits, or lack thereof, of introducing E10 to Mexico. An injunction was granted in October 2017, preventing the blending and selling of E10, but was overturned by a higher court in June 2018, making it legal to blend and sell E10 by PEMEX throughout Mexico except for its three largest metropolitan areas. On January 15, 2020, the Mexican Supreme Court ruled that the expedited process for the CRE regulation was unconstitutional, and that after a 180 day period the maximum ethanol blend allowed in the country would revert to 5.8%. There was an effort to go through the full regulatory process to allow for 10% blends countrywide, including in the three major metropolitan areas. The 180 day window was extended multiple times due to COVID-19, but eventually lapsed in June 2021, decreasing the maximum ethanol blend back to 5.8%.

In January 2020, the updated North American Free Trade Agreement, known as the United States Mexico Canada Agreement or USMCA was signed. The USMCA went into effect on July 1, 2020, and maintains the duty free access of U.S. agricultural commodities, including ethanol, into Canada and Mexico. According to the U.S. Department of Agriculture Foreign Agricultural Service, exports to Canada were 326 mmg and exports to Mexico were 64 mmg in 2020.

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Impact of COVID-19

The COVID-19 pandemic and related economic repercussions have created significant volatility, uncertainty, and turmoil in the energy industry. The situation surrounding COVID-19 continues to evolve and the ultimate duration and impact of the outbreak remains highly uncertain and subject to change.

We continue to closely monitor the impact of COVID-19 on all aspects of our business, including how it will impact our employees, customers, vendors, and business partners. For the nine months ended September 30, 2021, there has been no adverse effect due to COVID-19 on our ability to maintain operations, including our financial reporting systems, our internal controls over financial reporting or our disclosure controls and procedures. Although we did not incur significant disruptions during the three and nine months ended September 30, 2021, from COVID-19, we are unable to predict the impact that COVID-19 will have on our future financial position and operating results due to numerous uncertainties.

For further information regarding the impact of COVID-19 and the decline in oil demand on the company, please see Part I, Item 1A, “Risk Factors,” of our 2020 annual report.

Comparability of our Financial Results

There are various events that affect comparability of our operating results from 2021 to 2020, including the sale of our 50% interest of GPCC in October 2020, the sale of our Hereford, Texas plant in December 2020, the acquisition of a majority interest in FQT in December 2020 and the disposition of our Ord, Nebraska plant in March 2021.

We report the financial and operating performance for the following four operating segments: (1) ethanol production, which includes the production of ethanol, including industrial-grade alcohol, distillers grains, Ultra-High Protein and corn oil, (2) agribusiness and energy services, which includes grain handling and storage, commodity marketing and merchant trading for company-produced and third-party ethanol, distillers grains, corn oil, natural gas and other commodities, (3) food and ingredients, which includes food-grade corn oil and (4) partnership, which includes fuel storage and transportation services. The food and ingredients segment had no activity during the three and nine months ended September 30, 2021 and 2020.

During the normal course of business, our operating segments do business with each other. For example, our agribusiness and energy services segment procures grain and natural gas and sells products, including ethanol, distillers grains and corn oil of our ethanol production segment. Our partnership segment provides fuel storage and transportation services for our agribusiness and energy services segment. These intersegment activities are treated like third-party transactions with origination, marketing and storage fees charged at estimated market values. Consequently, these transactions affect segment performance; however, they do not impact our consolidated results since the revenues and corresponding costs are eliminated.

Corporate activities include selling, general and administrative expenses, consisting primarily of compensation, professional fees and overhead costs not directly related to a specific operating segment. When we evaluate segment performance, we review the following segment information as well as earnings before interest, income taxes, depreciation and amortization, excluding amortization of operating lease right-of-use assets and amortization of debt issuance costs, or EBITDA.

As of September 30, 2021, we, together with our subsidiaries, own a 48.9% limited partner interest and a 2.0% general partner interest in the partnership and own all of the partnership’s incentive distribution rights, with the remaining 49.1% limited partner interest owned by public common unitholders. We consolidate the financial results of the partnership, and record a noncontrolling interest for the economic interest in the partnership held by the public common unitholders.

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Segment Results

The selected operating segment financial information are as follows (in thousands):

	Three Months Ended ‎September 30,				%	Nine Months Ended ‎September 30,				%
	2021		2020		Variance	2021		2020		Variance
Revenues:
Ethanol production:
Revenues from external customers	$	588,349	$	332,953	76.7%	$	1,567,344	$	1,099,170	42.6%
Intersegment revenues		-		25	*		-		75	*
Total segment revenues		588,349		332,978	76.7		1,567,344		1,099,245	42.6
Agribusiness and energy services:
Revenues from external customers		157,412		90,074	74.8		454,208		342,078	32.8
Intersegment revenues		5,362		5,354	0.1		15,997		17,030	(6.1)
Total segment revenues		162,774		95,428	70.6		470,205		359,108	30.9
Partnership:
Revenues from external customers		1,030		1,035	(0.5)		3,297		3,707	(11.1)
Intersegment revenues		18,221		20,347	(10.4)		56,061		58,327	(3.9)
Total segment revenues		19,251		21,382	(10.0)		59,358		62,034	(4.3)
Revenues including intersegment activity		770,374		449,788	71.3		2,096,907		1,520,387	37.9
Intersegment eliminations		(23,583)		(25,726)	(8.3)		(72,058)		(75,432)	(4.5)
Revenues as reported	$	746,791	$	424,062	76.1%	$	2,024,849	$	1,444,955	40.1%

	Three Months Ended ‎September 30,				%	Nine Months Ended ‎September 30,				%
	2021		2020		Variance	2021		2020		Variance
Cost of goods sold:
Ethanol production	$	597,854	$	330,162	81.1%	$	1,507,035	$	1,103,486	36.6%
Agribusiness and energy services		154,427		87,027	77.4		440,682		339,332	29.9
Intersegment eliminations		(22,102)		(23,256)	(5.0)		(68,897)		(70,761)	(2.6)
	$	730,179	$	393,933	85.4%	$	1,878,820	$	1,372,057	36.9%

	Three Months Ended ‎September 30,				%	Nine Months Ended ‎September 30,				%
	2021		2020		Variance	2021		2020		Variance
Operating income (loss):
Ethanol production (1)	$	(44,192)	$	(21,351)	107.0%	$	(30,969)	$	(100,924)	(69.3%)
Agribusiness and energy services		3,225		4,296	(24.9%)		15,720		7,207	118.1
Partnership		12,417		12,986	(4.4)		37,204		37,641	(1.2)
Intersegment eliminations		(1,481)		(2,447)	(39.5)		(3,161)		(4,597)	(31.2)
Corporate activities (2)		(14,644)		(7,689)	90.5		(1,089)		(27,228)	(96.0)
	$	(44,675)	$	(14,205)	*	$	17,705	$	(87,901)	*

(1)Operating loss for ethanol production includes a goodwill impairment charge of $24.1 million for the nine months ended September 30, 2020.

(2)Corporate activities for the three and nine months ended September 30, 2021 includes a $1.8 million loss on sale of assets and a $31.2 million gain on sale of assets, respectively, as well as a gain on sale of assets of $2.0 million for both the three and nine months ended September 30, 2020.

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	Three Months Ended ‎September 30,				%	Nine Months Ended ‎September 30,				%
	2021		2020		Variance	2021		2020		Variance
Depreciation and amortization:
Ethanol production	$	25,644	$	17,493	46.6%	$	62,655	$	50,575	23.9%
Agribusiness and energy services		870		655	32.8		2,072		1,764	17.5
Partnership		1,089		940	15.9		2,771		2,867	(3.3)
Corporate activities		677		665	1.8		1,995		2,002	(0.3)
	$	28,280	$	19,753	43.2%	$	69,493	$	57,208	21.5%

* Percentage variance not considered meaningful.

We use EBITDA and adjusted EBITDA as segment measures of profitability to compare the financial performance of our reportable segments and manage those segments. EBITDA is defined as earnings before interest expense, income tax expense, including related tax expense of equity method investments, depreciation and amortization excluding the amortization of right-of-use assets and debt issuance costs. Adjusted EBITDA includes adjustments related to gains or losses on sale of assets, our proportional share of EBITDA adjustments of our equity method investees and noncash goodwill impairment. We believe EBITDA and adjusted EBITDA are useful measures to compare our performance against other companies. EBITDA and adjusted EBITDA should not be considered an alternative to, or more meaningful than, net income, which is prepared in accordance with GAAP. EBITDA and adjusted EBITDA calculations may vary from company to company. Accordingly, our computation of EBITDA and adjusted EBITDA may not be comparable with a similarly titled measure of other companies.

The following table reconciles net loss including noncontrolling interest to adjusted EBITDA (in thousands):

	Three Months Ended ‎September 30,				Nine Months Ended ‎September 30,
	2021		2020		2021		2020
Net loss	$	(54,411)	$	(30,733)	$	(40,273)	$	(46,554)
Interest expense (1)		9,488		10,169		60,225		29,536
Income tax expense (benefit), net of equity method income tax expense		7		7,518		(2,914)		(41,957)
Depreciation and amortization (2)		28,280		19,753		69,493		57,208
EBITDA		(16,636)		6,707		86,531		(1,767)
Loss (gain) on sale of assets, net		1,823		(2,000)		(31,245)		(2,000)
Proportional share of EBITDA adjustments to equity method investees		45		2,071		139		7,049
Noncash goodwill impairment		-		-		-		24,091
Adjusted EBITDA	$	(14,768)	$	6,778	$	55,425	$	27,373

(1)Interest expense for the nine months ended September 30, 2021 includes a loss upon extinguishment of convertible notes of $22.1 million and a loss on settlement of convertible notes of $9.5 million.

(2)Excludes the change in operating lease right-of-use assets and amortization of debt issuance costs.

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The following table reconciles segment EBITDA to consolidated adjusted EBITDA (in thousands):

	Three Months Ended ‎September 30,				%	Nine Months Ended ‎September 30,				%
	2021		2020		Variance	2021		2020		Variance
Adjusted EBITDA:
Ethanol production	$	(18,524)	$	(3,856)	*	$	31,739	$	(49,588)	164.0%
Agribusiness and energy services		3,818		4,950	(22.9)		17,515		9,115	92.2
Partnership		13,679		14,082	(2.9)		40,492		40,996	(1.2)
Intersegment eliminations		(1,480)		(2,447)	(39.5)		(3,160)		(4,597)	(31.3)
Corporate activities (1)		(14,129)		(6,022)	134.6		(55)		2,307	(102.4)
EBITDA		(16,636)		6,707	*		86,531		(1,767)	*
Loss (gain) on sale of assets, net		1,823		(2,000)	*		(31,245)		(2,000)	*
Proportional share of EBITDA adjustments to equity method investees		45		2,071	(97.8)		139		7,049	(98.0)
Noncash goodwill impairment		-		-	*		-		24,091	*
Adjusted EBITDA	$	(14,768)	$	6,778	*	$	55,425	$	27,373	102.5%

(1)Includes corporate expenses, offset by the loss on sale of assets of $1.8 million and the gain on sale of assets of $31.2 million for the three and nine months ended September 30, 2021, respectively, the gain on sale of assets of $2.0 million for both the three and nine months for the three and nine months ended September 30, 2020 and earnings from equity method investments of $0.6 million and $20.4 million for the three and nine months ended September 30, 2020, respectively.

* Percentage variance not considered meaningful.

Three Months Ended September 30, 2021 Compared with the Three Months Ended September 30, 2020

Consolidated Results

Consolidated revenues increased $322.7 million for the three months ended September 30, 2021, compared with the same period in 2020, primarily due to higher prices on ethanol, distillers grains and corn oil and increased trading revenues within our agribusiness and energy services segment.

Operating loss increased $30.5 million and adjusted EBITDA decreased $21.5 million for the three months ended September 30, 2021, compared with the same period last year primarily due to decreased margins on ethanol production. Interest expense decreased $0.7 million for the three months ended September 30, 2021, compared with the same period in 2020. Income tax expense was $7 thousand for the three months ended September 30, 2021, compared with income tax expense of $7.3 million for the same period in 2020 primarily due to the recording of a valuation allowance against tax NOLs arising during the three months ended September 30, 2020.

The following discussion provides greater detail about our third quarter segment performance.

Ethanol Production Segment

Key operating data for our ethanol production segment is as follows:

	Three Months Ended September 30,
	2021	2020	% Variance
Ethanol sold
(thousands of gallons)	181,214	189,202	(4.2)
Distillers grains sold
(thousands of equivalent dried tons)	492	479	2.7
Corn oil sold
(thousands of pounds)	55,397	50,953	8.7
Corn consumed
(thousands of bushels)	62,524	65,284	(4.2)

Revenues in our ethanol production segment increased $255.4 million for the three months ended September 30, 2021, compared with the same period in 2020, primarily due to higher prices of ethanol, distillers grains and corn oil.

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Cost of goods sold for our ethanol production segment increased $267.7 million for the three months ended September 30, 2021, compared with the same period last year primarily due to higher corn costs. Operating loss increased $22.8 million and EBITDA decreased $14.7 million for the three months ended September 30, 2021, compared with the same period in 2020 primarily due to decreased margins on ethanol production. Depreciation and amortization expense for the ethanol production segment was $25.6 million for the three months ended September 30, 2021, compared with $17.5 million for the same period last year, with the increase driven primarily by accelerated depreciation on assets retired in conjunction with Project 24 and other plant improvements.

Agribusiness and Energy Services Segment

Revenues in our agribusiness and energy services segment increased $67.3 million while operating loss and EBITDA decreased $1.1 million for the three months ended September 30, 2021, compared with the same period in 2020. The increase in revenues was primarily due to an increase in ethanol, distillers grain and corn oil trading activity driven by higher prices. Operating loss and EBITDA decreased primarily as a result of lower trading margins.

Food and Ingredients Segment

The food and ingredients segment, which now represents food-grade corn oil production, had no activity during the three months ended September 30, 2021.

Partnership Segment

Revenues generated by our partnership segment decreased $2.1 million for the three months ended September 30, 2021, compared with the same period for 2020. Railcar transportation services revenue decreased $0.9 million primarily due to a reduction in average volumetric capacity provided, and storage and throughput services revenue decreased $1.0 million due to a decrease in throughput volumes, both of which were a result of the sale of our Hereford ethanol plant in the fourth quarter of 2020 and our Ord ethanol plant in the first quarter of 2021. Terminal services revenue decreased $0.1 million due to lower throughput at our terminals. Trucking and other revenue decreased $0.1 million as a result of lower affiliate freight volume. Operating income decreased $0.6 million and EBITDA decreased $0.4 million for the three months ended September 30, 2021 compared with the same period in 2020.

Intersegment Eliminations

Intersegment eliminations of revenues decreased by $2.1 million for the three months ended September 30, 2021 compared with the same period in 2020 primarily due to decreased partnership revenues.

Corporate Activities

Operating income was impacted by an increase in corporate activities of $7.0 million for the three months ended September 30, 2021, compared to the same period in 2020, primarily due to the estimated loss of $2.0 million associated with the contingent earn-out provisions on the sale of GPCC recorded during the three months ended September 30, 2021, the gain of $2.0 million associated with the recognition of earn-out provisions related to the initial sale of GPCC for the three months ended September 30, 2020, as well as higher personnel costs.

Income Taxes

We recorded income tax expense of $7 thousand for the three months ended September 30, 2021, compared with income tax expense of $7.3 million for the same period in 2020. The decrease in the amount of tax expense recorded for the three months ended September 30, 2021 was primarily due to a decrease in pretax book income offset by the recording of a valuation allowance against the tax net operating loss generated in the period.

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Nine Months Ended September 30, 2021 Compared with the Nine Months Ended September 30, 2020

Consolidated Results

Consolidated revenues increased $579.9 million for the nine months ended September 30, 2021, compared with the same period in 2020, primarily due to higher prices on ethanol, distillers grains and corn oil and increased trading revenues within our agribusiness and energy services segment.

Operating income increased $105.6 million and for the nine months ended September 30, 2021, compared with the same period last year primarily due to the $31.2 million gain on sale of assets and improved margins on ethanol production during the second quarter of 2021, as well as the goodwill impairment charge of $24.1 million during the first quarter of 2020. Adjusted EBITDA increased $28.1 million due to improved margins on ethanol production and higher margins in our agribusiness and energy services segment. Interest expense increased $30.7 million for the nine months ended September 30, 2021 compared with the same period in 2020 due to the loss upon settlement of convertible notes of $22.1 million, recorded in the first quarter and the $9.5 million loss upon settlement of convertible notes recorded in the second quarter. Income tax benefit was $2.9 million for the nine months ended September 30, 2021, compared with income tax benefit of $48.5 million for the same period in 2020, primarily due to benefits recorded related to the CARES Act during the nine months ended September 30, 2020.

The following discussion provides greater detail about our year-to-date segment performance.

Ethanol Production Segment

Key operating data for our ethanol production segment is as follows:

	Nine Months Ended ‎September 30,
	2021	2020	% Variance
Ethanol sold
(thousands of gallons)	550,127	579,540	(5.1)
Distillers grains sold
(thousands of equivalent dried tons)	1,459	1,504	(3.0)
Corn oil sold
(thousands of pounds)	156,835	153,001	2.5
Corn consumed
(thousands of bushels)	189,544	201,075	(5.7)

Revenues in our ethanol production segment increased $468.1 million for the nine months ended September 30, 2021, compared with the same period in 2020 primarily due to higher prices on ethanol, distillers grains and corn oil, offset by lower ethanol volumes sold.

Cost of goods sold for our ethanol production segment increased $403.5 million for the nine months ended September 30, 2021, compared with the same period last year primarily due to higher corn costs. Operating income increased $70.0 million and EBITDA increased $81.3 million for the nine months ended September 30, 2021 compared with the same period in 2020 primarily due to improved margins as well as the $24.1 million noncash impairment charge recorded during the three months ended March 31, 2020. Depreciation and amortization expense for the ethanol production segment was $62.7 million for the nine months ended September 30, 2021 compared with $50.6 million for the same period last year.

Agribusiness and Energy Services Segment

Revenues in our agribusiness and energy services segment increased $111.1 million while operating income increased $8.5 million and EBITDA increased $8.4 million for the nine months ended September 30, 2021, compared with the same period in 2020. The increase in revenues was primarily due to an increase in ethanol, distillers grain and corn oil trading activity. Operating income and EBITDA increased primarily as a result of higher trading margins.

Food and Ingredients Segment

The food and ingredients segment, which now represents food-grade corn oil production had no activity during the nine months ended September 30, 2021.

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Partnership Segment

Revenues generated by our partnership segment decreased $2.7 million for the nine months ended September 30, 2021, compared with the same period for 2020. Railcar transportation services revenue decreased $1.5 million due to a reduction in average volumetric capacity provided and lower sublease revenue. Storage and throughput services revenue decreased $0.7 million due to a decrease in throughput volumes as a result of our sale of the Hereford ethanol plant in the fourth quarter of 2020 and our Ord ethanol plant in the first quarter of 2021. Trucking and other revenue decreased $0.2 million as a result of lower third party freight volume. Terminal services revenue decreased $0.2 million due to lower throughput at our terminals. Operating income decreased $0.4 million and EBITDA decreased $0.5 million for the nine months ended September 30, 2021 compared with the same period in 2020.

Intersegment Eliminations

Intersegment eliminations of revenues decreased by $3.4 million for the nine months ended September 30, 2021 compared with the same period in 2020 primarily due to decreased partnership revenues and intersegment marketing and service fees within the agribusiness and energy services segment as a result of lower production volumes.

Corporate Activities

Operating income was impacted by an increase in corporate activities of $26.1 million for the nine months ended September 30, 2021, compared to the same period in 2020, primarily due to the gain on sale of assets recorded during the second quarter of 2021.

Income Taxes

We recorded income tax benefit of $2.9 million for the nine months ended September 30, 2021, compared with income tax benefit of $48.5 million for the same period in 2020. The decrease in the amount of tax benefit was primarily due to an increase in pretax book income compared to the tax benefit recorded for the same period in 2020 to reflect the benefit associated with the carry back of the 2019 tax NOLs to the 2014 tax year under the CARES Act of 2020, as well as the release of a previously recorded valuation allowance against the 2019 NOL and other deferred tax assets.

Income from Equity Method Investees

Income from equity method investees decreased $20.4 million for the nine months ended September 30, 2021 compared with the same period last year due primarily to the disposition of our GPCC joint venture during the fourth quarter of 2020.

Liquidity and Capital Resources

Our principal sources of liquidity include cash generated from operating activities and bank credit facilities. We fund our operating expenses and service debt primarily with operating cash flows. Capital resources for maintenance and growth expenditures are funded by a variety of sources, including cash generated from operating activities, borrowings under bank credit facilities, or issuance of senior notes or equity. Our ability to access capital markets for debt under reasonable terms depends on our financial condition, credit ratings and market conditions. We believe that our ability to obtain financing at reasonable rates and history of positive cash flow from operating activities, which have been positive for seven of the previous ten years, provide a solid foundation to meet our future liquidity and capital resource requirements.

On September 30, 2021, we had $589.8 million in cash and equivalents, excluding restricted cash, consisting of $497.6 million held at our parent company and the remainder held at our subsidiaries. Additionally, we had $131.1 million in restricted cash at September 30, 2021. We also had $312.6 million available under our committed revolving credit and term loan agreements, some of which were subject to restrictions or other lending conditions. Funds at certain subsidiaries are generally required for their ongoing operational needs and restricted from distribution. At September 30, 2021, our subsidiaries had approximately $174.4 million of net assets that were not available to use in the form of dividends, loans or advances due to restrictions contained in their credit facilities.

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Net cash used in operating activities was $27.9 million for the nine months ended September 30, 2021, compared with net cash provided by operating activities of $76.4 million for the same period in 2020. Operating activities compared to the prior year were primarily affected by changes in working capital when compared to the same period of the prior year. Net cash used in investing activities was $43.5 million for the nine months ended September 30, 2021, compared with net cash used in investing activities of $89.5 million for the same period in 2020. Investing activities compared to the prior year were primarily affected by proceeds from the sale of assets during 2021. Net cash provided by financing activities was $517.4 million for the nine months ended September 30, 2021, compared with net cash used in financing activities of $74.6 million for the same period in 2020, primarily due to proceeds from the issuance of common stock and debt offerings during 2021.

Additionally, Green Plains Trade, Green Plains Grain and Green Plains Commodity Management use revolving credit facilities to finance working capital requirements. We frequently draw from and repay these facilities, which results in significant cash movements reflected on a gross basis within financing activities as proceeds from and payments on short-term borrowings.

We incurred capital expenditures of approximately $123.7 million during the nine months ended September 30, 2021, primarily for Ultra High-Protein expansion projects at various facilities, Project 24 operating expense reduction and for various maintenance projects. Capital spending for the remainder of 2021 is expected to be between $75.0 million and $100.0 million for various projects, including the Ultra High-Protein expansion at our Wood River, Obion, Central City and Mount Vernon locations, which are expected to be financed with cash provided by operating activities, as well as available borrowings under our $75.0 million delayed draw loan and cash on hand.

Our business is highly sensitive to the price of commodities, particularly for corn, ethanol, distillers grains, corn oil and natural gas. We use derivative financial instruments to reduce the market risk associated with fluctuations in commodity prices. Sudden changes in commodity prices may require cash deposits with brokers for margin calls or significant liquidity with little advanced notice to meet margin calls, depending on our open derivative positions. We continuously monitor our exposure to margin calls and believe we will continue to maintain adequate liquidity to cover margin calls from our operating results and borrowings.

For each calendar quarter commencing with the quarter ended September 30, 2015, the partnership agreement requires the partnership to distribute all available cash, as defined, to its partners, including us, within 45 days after the end of each calendar quarter. Available cash generally means all cash and cash equivalents on hand at the end of that quarter less cash reserves established by the general partner, including those for future capital expenditures, future acquisitions and anticipated future debt service requirements, plus all or any portion of the cash on hand resulting from working capital borrowings made subsequent to the end of that quarter. On October 19, 2021, the board of directors of the general partner of the partnership declared a cash distribution of $0.435 per unit on outstanding common and subordinated units. The distribution is payable on November 12, 2021, to unitholders of record at the close of business on November 5, 2021.

Our board of directors authorized a share repurchase program of up to $200.0 million of our common stock. Under the program, we may repurchase shares in open market transactions, privately negotiated transactions, accelerated share buyback programs, tender offers or by other means. The timing and amount of repurchase transactions are determined by our management based on market conditions, share price, legal requirements and other factors. The program may be suspended, modified or discontinued at any time without prior notice. We did not repurchase any shares during the third quarter of 2021. To date, we have repurchased 7,396,936 of common stock for approximately $92.8 million under the program.

We believe we have sufficient working capital for our existing operations. A continued sustained period of unprofitable operations, however, may strain our liquidity. We may sell additional assets or equity or borrow capital to improve or preserve our liquidity, expand our business or acquire businesses. We cannot provide assurance that we will be able to secure funding necessary for additional working capital or these projects at reasonable terms, if at all.

Debt

For additional information related to our debt, see Note 8 – Debt included as part of the notes to consolidated financial statements and Note 12 – 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, 2020.

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We were in compliance with our debt covenants at September 30, 2021. Based on our forecasts, we believe we will maintain compliance at each of our subsidiaries for the next twelve months or have sufficient liquidity available on a consolidated basis to resolve noncompliance. We cannot provide assurance that actual 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 a subsidiary is unable to comply with its debt covenants, the subsidiary’s lenders may determine that an event of default has occurred, and following notice, the lenders may terminate the commitment and declare the unpaid balance due and payable.

As outlined in Note 8 - Debt, we use LIBOR as a reference rate for various credit facilities. The administrator of LIBOR has announced it will cease the publication of the one week and two month LIBOR settings immediately following the LIBOR publication on December 31, 2021, and the remaining USD LIBOR settings immediately following the LIBOR publication on June 30, 2023. It is unclear if LIBOR will cease to exist or if new methods of calculating LIBOR will be established by the applicable phase out dates. We expect to amend our credit facilities to determine the interest rate to replace LIBOR with the new standard that is established. The potential effect of any such event on interest expense cannot yet be determined.

Corporate Activities

In March 2021, we issued $230.0 million of 2.25% convertible senior notes due in 2027, or the 2.25% notes. The 2.25% notes bear interest at a rate of 2.25% per year, payable on March 15 and September 15 of each year, beginning September 15, 2021. The initial conversion rate is 31.6206 shares of the company’s common stock per $1,000 principal amount of 2.25% notes (equivalent to an initial conversion price of approximately $31.62 per share of the company’s common stock), representing an approximately 37.5% premium over the offering price of the company’s common stock. The conversion rate is subject to adjustment upon the occurrence of certain events, including but not limited to; the event of a stock dividend or stock split; the issuance of additional rights, options and warrants; spinoffs; the event of a cash dividend or distribution; or a tender or exchange offering. In addition, the company may be obligated to increase the conversion rate for any conversion that occurs in connection with certain corporate events, including the company’s calling the 2.25% notes for redemption. We may settle the 2.25% notes in cash, common stock or a combination of cash and common stock. At September 30, 2021, the outstanding principal balance on the 2.25% notes was $230.0 million.

In June 2019, we issued $115.0 million of 4.00% convertible senior notes due in 2024, or the 4.00% notes. The 4.00% notes are senior, unsecured obligations, with interest payable on January 1 and July 1 of each year, beginning January 1, 2020, at a rate of 4.00% per annum. The initial conversion rate will be 64.1540 shares of our common stock per $1,000 principal amount of the 4.00% notes, which is equivalent to an initial conversion price of approximately $15.59 per share of our common stock. The conversion rate will be subject to adjustment upon the occurrence of certain events, including but not limited to; the event of a stock dividend or stock split; the issuance of additional rights, options and warrants; spinoffs; the event of a cash dividend or distribution; or a tender or exchange offering. In addition, we may be obligated to increase the conversion rate for any conversion that occurs in connection with certain corporate events, including our calling the 4.00% notes for redemption. We may settle the 4.00% notes in cash, common stock or a combination of cash and common stock.

In May 2021, we entered into a privately negotiated agreement with certain noteholders of the company’s 4.00% notes. Under this agreement, 3,568,705 shares of our common stock were exchanged for $51.0 million in aggregate principal amount of the 4.00% notes. Common stock held as treasury shares were exchanged for the 4.00% notes. At September 30, 2021, the outstanding principal balance on the 4.00% notes was $64.0 million.

In August 2016, we issued $170.0 million of 4.125% convertible senior notes due in 2022, or 4.125% notes, which are senior, unsecured obligations with interest payable on March 1 and September 1 of each year. Prior to March 1, 2022, the 4.125% notes are not convertible unless certain conditions are satisfied. The initial conversion rate is 35.7143 shares of common stock per $1,000 of principal which is equal to a conversion price of approximately $28.00 per share. The conversion rate will be subject to adjustment upon the occurrence of certain events, including but not limited to; the event of a stock dividend or stock split; the issuance of additional rights, options and warrants; spinoffs; the event of a cash dividend or distribution; or a tender or exchange offering. We may settle the 4.125% notes in cash, common stock or a combination of cash and common stock.

In March 2021, concurrent with the issuance of the 2.25% notes, we used approximately $156.5 million of the net proceeds of the 2.25% notes to repurchase approximately $135.7 million aggregate principal amount of its 4.125% notes due 2022, in privately negotiated transactions. At September 30, 2021, the outstanding principal balance on the 4.125% notes was $34.3 million.

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Agribusiness and Energy Services Segment

Green Plains Trade has a $300.0 million senior secured asset-based revolving credit facility to finance working capital up to the maximum commitment based on eligible collateral, which matures in July of 2022. This facility can be increased by up to $70.0 million with agent approval. Advances are subject to variable interest rates equal to a daily LIBOR rate plus 2.25% or the base rate plus 1.25%. The unused portion of the credit facility is also subject to a commitment fee of 0.375% per annum. At September 30, 2021, the outstanding principal balance was $109.6 million on the facility and the interest rate was 2.40%.

Green Plains Grain has a $100.0 million senior secured asset-based revolving credit facility to finance working capital up to the maximum commitment based on eligible collateral, which matures in June of 2022. This facility can be increased by up to $75.0 million with agent approval and up to $50.0 million for seasonal borrowings. Total commitments outstanding under the facility cannot exceed $225.0 million. At September 30, 2021, the outstanding principal balance was $22.8 million on the facility and the interest rate was 5.25%.

Green Plains Grain has short-term inventory financing agreements with a financial institution with a maximum commitment of up to $50.0 million, which matures June 2022. Green Plains Grain 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. Green Plains Grain had no short-term notes payable related to these inventory financing agreements as of September 30, 2021.

Green Plains Commodity Management has an uncommitted $30.0 million revolving credit facility which matures April 30, 2023, to finance margins related to its hedging programs. Advances are subject to variable interest rates equal to LIBOR plus 1.75%. At September 30, 2021, the outstanding principal balance was $30.0 million on the facility and the interest rate was 1.82%.

Ethanol Production Segment

On February 9, 2021, Green Plains SPE LLC, a wholly-owned special purpose subsidiary and parent of Green Plains Obion and Green Plains Mount Vernon issued $125.0 million of junior secured mezzanine notes due 2026 with BlackRock for the purchase of all notes issued. At September 30, 2021, the outstanding principal balance was $125.0 million on the loan and the interest rate was 11.75%.

Green Plains Wood River and Green Plains Shenandoah, wholly-owned subsidiaries of the company, have a $75.0 million delayed draw loan agreement, which matures on September 1, 2035. At September 30, 2021, the outstanding principal balance was $30.0 million on the loan and the interest rate was 6.52%.

We also have small equipment financing loans, finance leases on equipment or facilities, and other forms of debt financing.

Partnership Segment

As of September 30, 2021, Green Plains Partners, through a wholly owned subsidiary, had a term loan to fund working capital, capital expenditures and other general partnership purposes. On July 20, 2021, the partnership entered into an Amended and Restated Credit Agreement (“Amended Credit Facility”) to our existing credit facility with BlackRock and TMI Trust Company as administrative agent. The Amended Credit Facility decreased the total amount available to $60.0 million, extended the maturity from December 31, 2021 to July 20, 2026, and converted the balance to a term loan. The term loan does not require any principal payments; however, the partnership has the option to prepay $1.5 million per quarter beginning twelve months after the closing date. As of September 30, 2021, the term loan had a balance of $60.0 million and an interest rate of 8.13%.

Under the terms of the amended agreement, BlackRock purchased the outstanding balance of the existing notes from the previous lenders. Interest on the term loan is based on 3-month LIBOR plus 8.00%, with a 0% LIBOR floor and is payable on the 15^th day of each March, June, September and December, during the term, with the first interest payment being September 15, 2021. Financial covenants of the amended agreement include a maximum consolidated leverage ratio of 2.5x and a minimum consolidated debt service coverage ratio of 1.10x. The Amended Credit Facility continues to be secured by substantially all of the assets of the partnership.

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During the nine months ended September 30, 2021, prior to the amendment, principal payments of $50.0 million were made on the previous credit facility, including $19.5 million of scheduled repayments, $27.5 million related to the sale of the storage assets located adjacent to the Ord, Nebraska ethanol plant and a $3.0 million prepayment made with excess cash.

Contractual Obligations

Contractual obligations as of September 30, 2021 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)	$	721,366	$	197,117	$	67,642	$	188,629	$	267,978
Interest and fees on debt obligations (2)		178,697		9,051		62,623		73,023		34,000
Operating lease obligations (3)		81,087		19,497		31,331		15,817		14,442
Other		24,447		3,450		4,108		9,349		7,540
Purchase obligations:
Forward grain purchase contracts (4)		226,253		222,806		3,447		-		-
Other commodity purchase contracts (5)		146,472		129,447		13,567		3,458		-
Other		1,167		912		255		-		-
Total contractual obligations	$	1,379,489	$	582,280	$	182,973	$	290,276	$	323,960

(1)Includes the current portion of long-term debt and future finance lease obligations and excludes the effect of any debt issuance costs.

(2)Interest amounts are calculated over the terms of the loans using current interest rates, assuming scheduled principal 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 and exclude leases not yet commenced with undiscounted future lease payments of approximately $0.7 million.

(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.

Critical Accounting Policies and Estimates

Key accounting policies, including those relating to revenue recognition, 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. Information about our critical accounting policies and estimates are included in our annual report on Form 10-K for the year ended December 31, 2020.

Off-Balance Sheet Arrangements

We do not have any off-balance sheet arrangements.

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

We use various financial instruments to manage and reduce our exposure to various market risks, including changes in commodity prices and interest rates. We conduct all of our business in U.S. dollars and are not currently exposed to foreign currency risk.

Interest Rate Risk

We are exposed to interest rate risk through our loans which bear interest at variable rates. Interest rates on our variable-rate debt are based on the market rate for the lender’s prime rate or LIBOR. A 10% increase in interest rates would affect our interest cost by approximately $0.9 million per year. At September 30, 2021, we had $711.4 million in debt, $222.0 million of which had variable interest rates.

For additional information related to our debt, see Note 8 – Debt included as part of the notes to consolidated financial statements and Note 12 – 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, 2020.

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Commodity Price Risk

Our business is highly sensitive to commodity price risk, particularly for ethanol, corn, distillers grains, corn oil and natural gas. Ethanol prices are sensitive to world crude oil supply and demand, the price of crude oil, gasoline and corn, the price of substitute fuels, refining capacity and utilization, government regulation and consumer demand for alternative fuels. Corn prices are affected by weather conditions, yield, changes in domestic and global supply and demand, and government programs and policies. Distillers grains prices are impacted by livestock numbers on feed, prices for feed alternatives and supply, which is associated with ethanol plant production. Natural gas prices are influenced by severe weather in the summer and winter and hurricanes in the spring, summer and fall. Other factors include North American energy exploration and production, and the amount of natural gas in underground storage during injection and withdrawal seasons.

To reduce the risk associated with fluctuations in the price of ethanol, corn, distillers grains, corn oil, and natural gas, at times we use forward fixed-price physical contracts and derivative financial instruments, such as futures and options executed on the Chicago Board of Trade, the New York Mercantile Exchange and the Chicago Mercantile Exchange. We focus on locking in favorable operating margins, when available, using a model that continually monitors market prices for corn, natural gas and other inputs relative to the price for ethanol and distillers grains at each of our production facilities. We create offsetting positions using a combination of forward fixed-price purchases, sales contracts and derivative financial instruments. As a result, we frequently have gains on derivative financial instruments that are offset by losses on forward fixed-price physical contracts or inventories and vice versa. Our results are impacted by a mismatch of gains or losses associated with the derivative instrument during a reporting period when the physical commodity purchases or sale has not yet occurred. During the three and nine months ended September 30, 2021, revenues included net gains of $0.9 million and net losses of $89.8 million, respectively, and cost of goods sold included net losses of $17.4 million and net gains of $15.3 million, respectively, associated with derivative financial instruments.

Ethanol Production Segment

In the ethanol production segment, net gains and losses from settled derivative instruments are offset by physical commodity purchases or sales to achieve the intended operating margins. To reduce commodity price risk caused by market fluctuations, we enter into exchange-traded futures and options contracts that serve as economic hedges.

Our exposure to market risk, which includes the impact of our risk management activities resulting from our fixed-price purchase and sale contracts and derivatives, is based on the estimated net income effect resulting from a hypothetical 10% change in price for the next 12 months starting on September 30, 2021, which is as follows (in thousands):

Commodity	Estimated Total Volume ‎ Requirements for the ‎ Next 12 Months (1)	Unit of ‎Measure	Net Income Effect of ‎ Approximate 10% ‎Change in Price
Ethanol	958,000	Gallons	$	126,295
Corn	331,000	Bushels	$	136,086
Distillers grains	2,400	Tons (2)	$	28,190
Corn oil	258,000	Pounds	$	10,388
Natural gas	27,700	MmBTU	$	5,237

(1) Estimated volumes assume production at full capacity.

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

Agribusiness and Energy Services Segment

In the agribusiness and energy services segment, our inventories, physical purchase and sale contracts and derivatives are marked to market. To reduce commodity price risk caused by market fluctuations for purchase and sale commitments of grain and grain held in inventory, we enter into exchange-traded futures and options contracts that serve as economic hedges.

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The market value of exchange-traded futures and options used for hedging are highly correlated with the underlying market value of grain inventories and related purchase and sale contracts for grain. The less correlated portion of inventory and purchase and sale contract market values, 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. Inventory values are affected by the month-to-month spread in the futures markets. These spreads are also less volatile than overall market value of our inventory and tend to follow historical patterns, but cannot be mitigated directly. Our accounting policy for futures and options, as well as the underlying inventory held for sale and purchase and sale contracts, is to reflect their current market values and include gains and losses in the consolidated statement of operations.

Our daily net commodity position consists of inventories related to purchase and sale contracts and exchange-traded contracts. The fair value of our position was approximately $0.7 million for grain at September 30, 2021. Our market risk at that date, based on the estimated net income effect resulting from a hypothetical 10% change in price, was approximately $55 thousand.

Item 4. Controls and Procedures.

Evaluation of Disclosure Controls and Procedures

We maintain disclosure controls and procedures designed to ensure the information that must be disclosed in the reports we file or submit under the 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 management, as appropriate, to allow timely decisions regarding required financial disclosure. In designing and evaluating the disclosure controls and procedures, management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives. Management is required to apply its judgment in evaluating the cost-benefit relationship of possible controls and procedures.

Under the supervision and participation of our chief executive officer and chief financial officer, management carried out an evaluation of the effectiveness of the design and operation of our disclosure controls and procedures as of September 30, 2021, as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act and concluded that our disclosure controls and procedures were effective.

Changes in Internal Control over Financial Reporting

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 U.S. generally accepted accounting principles. There were no material changes in our internal control over financial reporting that occurred during the period covered by this 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 during the ordinary course of business. We do not believe this litigation will have a material adverse effect on our financial position, results of operations or cash flows.

Item 1A. Risk Factors.

Investors should carefully consider the discussion of risks and the other information in our annual report on Form 10-K for the year ended December 31, 2020, in Part I, Item 1A, “Risk Factors,” and the discussion of risks and other information in Part I, Item 2, “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” under “Cautionary Information Regarding Forward-Looking Statements,” of this report. Investors should also carefully consider the discussion of risks with the partnership under the heading “Risk Factors” and other information in their annual report on Form 10-K for the year ended December 31, 2020. 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. The following risk factors supplement and/or update risk factors previously disclosed and should be considered in conjunction with the other information included in, or incorporated by reference in, this quarterly report on Form 10-Q.

Our margins are dependent on managing the spread between the price of corn, natural gas, ethanol, including industrial-grade alcohol, distillers grains, Ultra-High Protein and corn oil.

Our operating results are highly sensitive to the spread between the corn and natural gas we purchase, and the ethanol, including industrial-grade alcohol, distillers grains, Ultra-High Protein and corn oil we sell. Price and supply are subject to various market forces, such as weather, domestic and global demand, shortages, export prices, crude oil prices, currency valuations and government policies in the United States and around the world, over which we have no control. Price volatility of these commodities may cause our operating results to fluctuate substantially. Increases in corn or natural gas prices or decreases in ethanol, including industrial-grade alcohol, distillers grains, Ultra-High Protein and corn oil prices may make it unprofitable to operate. No assurance can be given that we will purchase corn and natural gas or sell ethanol, including industrial-grade alcohol, distillers grains, Ultra-High Protein and corn oil at or near prices which would provide us with positive margins. Consequently, our results of operations and financial position may be adversely affected by increases in corn or natural gas prices or decreases in ethanol, including industrial-grade alcohol, distillers grains, Ultra-High Protein and corn oil prices.

We continuously monitor the margins at our ethanol plants using a variety of risk management tools and hedging strategies when appropriate. In recent years, the spread between ethanol and corn prices has fluctuated widely, narrowed significantly and been negative at times. Fluctuations are likely to continue. A sustained narrow spread or further reduction in the spread between ethanol and corn prices as a result of increased corn prices or decreased ethanol prices, would adversely affect our results of operations and financial position. Should our combined revenue from ethanol, including industrial-grade alcohol, distillers grains, Ultra-High Protein and corn oil fall below our cost of production, we could decide to slow or suspend production at some or all of our ethanol plants, which also could adversely affect our results of operations and financial position.

The commodities we buy and sell are subject to price volatility and uncertainty.

Our operating results are highly sensitive to commodity prices.

Corn. We are generally unable to pass increased corn costs to our customers since ethanol competes with other fuels. We have seen considerable price volatility in corn prices not experienced in recent years. At certain corn prices, ethanol may be uneconomical to produce. Ethanol plants, livestock industries and other corn-consuming enterprises put significant price pressure on local corn markets. In addition, local corn supplies and prices could be adversely affected by prices for alternative crops, increasing input costs, changes in government policies, shifts in global markets, supply or demand, or damaging growing conditions, such as plant disease or adverse weather, including drought.

Ethanol. Our revenues are dependent on market prices for ethanol which can be volatile as a result of a number of factors, including: the price and availability of competing fuels; the overall supply and demand for ethanol and corn; the price of gasoline, crude oil and corn; and government policies.

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Ethanol is marketed as a fuel additive that reduces vehicle emissions, an economical source of octanes and, to a lesser extent, a gasoline substitute. Consequently, gasoline supply and demand affect the price of ethanol. Should gasoline prices or demand decrease significantly, our results of operations could be materially impacted.

Ethanol imports also affect domestic supply and demand. Imported ethanol is not subject to an import tariff and, under the RFS II, sugarcane ethanol from Brazil is one of the most economical means for obligated parties to meet the advanced biofuel standard.

Industrial-grade alcohol is produced by further distillation processing of the 200-proof alcohol. Further distillation removes impurities which allows it to be used as an ingredient for sanitation products. Should industrial-grade alcohol prices or demand decrease significantly, our results of operations could be negatively impacted.

Distillers Grains. Increased U.S. dry mill ethanol production has resulted in increased distillers grains production. Should this trend continue, distillers grains prices could fall unless demand increases or other market sources are found. The price of distillers grains has historically been correlated with the price of corn. Occasionally, the price of distillers grains will lag behind fluctuations in corn or other feedstock prices, lowering our cost recovery percentage. Additionally, exports of distiller grains could be impacted by the enactment of foreign policy.

Distillers grains compete with other protein-based animal feed products. Downward pressure on other commodity prices, such as corn and soybeans, will generally cause the price of competing animal feed products to decline, resulting in downward pressure on the price of distillers grains.

Natural Gas. The price and availability of natural gas are subject to volatile market conditions. These market conditions are often affected by factors beyond our control, such as weather, drilling economics, overall economic conditions and government regulations. Significant disruptions in natural gas supply could impair our ability to produce ethanol. Furthermore, increases in natural gas prices or changes in our cost relative to our competitors cannot be passed on to our customers, which may adversely affect our results of operations and financial position.

Corn Oil. Industrial corn oil is generally marketed as a renewable diesel and biodiesel feedstock; therefore, the price of corn oil is affected by demand for renewable diesel and biodiesel. Expanded profitability in the renewable diesel and biodiesel industry due to the extended blending tax credit and low carbon fuels standards could impact corn oil demand. In general, corn oil prices follow the prices of heating oil and soybean oil. Decreases in the price of corn oil could have an unfavorable impact on our business.

Business disruptions due to unforeseen operational failures or factors outside of our control could impact our ability to fulfill contractual obligations.

Natural disasters, pandemics, transportation issues, significant track damage resulting from a train derailment or strikes by our transportation providers could delay shipments of raw materials to our plants or deliveries of ethanol, including industrial-grade alcohol, distillers grains, Ultra-High Protein and corn oil to our customers. If we are unable to meet customer demand or contract delivery requirements due to stalled operations caused by business disruptions, we could potentially lose customers.

Shifts in global markets, supply or demand changes, as well as adverse weather conditions, such as inadequate or excessive amounts of rain during the growing season, overly wet conditions, an early freeze or snowy weather during harvest could impact the supply of corn that is needed to produce ethanol. Corn stored in an open pile may be damaged by rain or warm weather before the corn is dried, shipped or moved into a storage structure.

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Government mandates affecting ethanol could change and impact the ethanol market.

Under the provisions of the Energy Independence and Security Act (EISA), Congress expanded the Renewable Fuel Standard (RFS II). The RFS II mandates the minimum volume of renewable fuels that must be blended into the transportation fuel supply each year which affects the domestic market for ethanol. Each year the Environmental Protection Agency (EPA) is supposed to undertake rulemaking to set the Renewable Volume Obligation (RVO) for the following year, though at times months or years pass without a finalized RVO. Further, the EPA has the authority to waive the requirements, in whole or in part, if there is inadequate domestic renewable fuel supply or the requirement severely harms the economy or the environment. After 2022, volumes shall be determined by the EPA in coordination with the Secretaries of Energy and Agriculture, taking into account such factors as impact on environment, energy security, future rates of production, cost to consumers, infrastructure, and other factors such as impact on commodity prices, job creation, rural economic development, or impact on food prices.

According to the RFS II, if mandatory renewable fuel volumes are reduced by at least 20% for two consecutive years, the EPA is required to modify, or reset, statutory volumes through 2022; the year through which the statutorily prescribed volumes run. While conventional ethanol maintained 15 billion gallons, 2019 was the second consecutive year that the total RVO was more than 20% below the statutory volumes levels. Thus, the EPA was expected to initiate a reset rulemaking, and modify statutory volumes through 2022, and do so based on the same factors they are to use in setting the RVOs post-2022. However, on December 19, 2019, the EPA announced it would not be moving forward with a reset rulemaking. It is unclear when or if they will propose a reset rulemaking. The EPA has stated an intention to propose a post-2022 ‘set’ rulemaking by the end of 2021.

Volumes can also be impacted as small refineries can petition the EPA for an SRE which, if approved, waives their portion of the annual RVO requirements. The EPA, through consultation with the DOE and the USDA, can grant them a full or partial waiver, or deny it outright within 90 days of submittal. A small refinery is defined as one that processes fewer than 75,000 barrels of petroleum per day.

Our operations could be adversely impacted by legislation, administration actions, EPA actions, or lawsuits that may reduce the RFS II mandated volumes of conventional ethanol and other biofuels through the annual RVO, the 2022 set rulemaking, the point of obligation for blending, or small refinery exemptions. A recent Supreme Court ruling held that the small refineries can continue to apply for an extension of their waivers from the RFS II, even if they have not been awarded a continuous string of exemptions. A recent D.C. Circuit Court of Appeals ruling held that the EPA overstepped its authority in extending the one pound Reid Vapor Pressure waiver for 10% ethanol blends to 15% ethanol blends in the summer, effectively limiting summertime sales of ethanol blends above 10% to flex fuel vehicles (FFVs) from June 1 to September 15 each year.

Similarly, should federal mandates regarding oxygenated gasoline be repealed, the market for domestic ethanol could be adversely impacted. Economic incentives to blend based on the relative value of gasoline versus ethanol, taking into consideration the octane value of ethanol, environmental requirements and the RFS II mandate, may affect future demand. A significant increase in supply beyond the RFS II mandate could have an adverse impact on ethanol prices. Moreover, changes to RFS II could negatively impact the price of ethanol or cause imported sugarcane ethanol to become more economical than domestic ethanol. Likewise, national, state and regional low carbon fuel standards (LCFS) like that of California, Oregon, Brazil or Canada could be favorable or harmful to conventional ethanol, depending on how the regulations are crafted, enforced and modified.

  Future demand may be influenced by economic incentives to blend based on the relative value of gasoline versus ethanol, taking into consideration the octane value of ethanol, environmental requirements and the value of RFS II credits or Renewable Identification Numbers (RINs). A significant increase in supply beyond the RFS II mandate could have an adverse impact on ethanol prices. Moreover, any changes to RFS II, whether by legislation, EPA action or lawsuit, originating from issues associated with the market price of RINs could negatively impact the demand for ethanol, discretionary blending of ethanol and/or the price of ethanol. Recent actions by the EPA to grant small refiner exemptions without accounting for the lost gallons, for example, resulted in lower RIN prices. Similarly, reducing annual RVO levels could also lead to lower RIN prices.

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Congress first enacted CAFE in 1975 to reduce energy consumption by increasing the fuel economy of cars and light trucks. FFVs, which are designed to run on a mixture of fuels, including higher blends of ethanol such as E85, used to receive preferential treatment in the form of corporate average fuel economy (CAFE) credits. There are approximately 21 million FFVs on the road in the U.S. today, 16 million of which are light duty trucks. FFV credits have been decreasing since 2014 and were completely phased out in 2020. Absent CAFE preferences or manufacturing tax credits, auto manufacturers may not be willing to build FFVs, which has the potential to slow the growth of E85 markets. However, California’s Low Carbon Fuel Standard program (LCFS) has driven growth in E85 usage, and other state/regional LCFS programs have the potential to do the same.

To the extent federal or state laws or regulations are modified and/or enacted, it may result in the demand for ethanol being reduced, which could negatively and materially affect our financial performance.

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

Employees surrender shares when restricted stock grants are vested to satisfy statutory minimum required payroll tax withholding obligations.

The following table lists the shares that were surrendered during the third quarter of 2021:

Period	Total Number of ‎ Shares Withheld for ‎Employee Awards	Average Price ‎Paid per Share
July 1 - July 31	2,976	$	34.07
August 1 - August 31	992		33.68
September 1 - September 30	-		-
Total	3,968	$	33.98

Our board of directors authorized a share repurchase program of up to $200 million of our common stock. Under this program, we may repurchase shares in open market transactions, privately negotiated transactions, accelerated buyback programs, tender offers or by other means. The timing and amount of the transactions are determined by management based on its evaluation of market conditions, share price, legal requirements and other factors. The program may be suspended, modified or discontinued at any time, without prior notice. We did not repurchase any shares during the third quarter of 2021. Since inception, the company has repurchased 7,396,936 shares of common stock for approximately $92.8 million under the program.

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 of Exhibit
3.1	Fourth Amended and Restated Bylaws of Green Plains Inc., dated September 27, 2021 (incorporated herein by reference to Exhibit 3.1 to the company’s Current Report on Form 8-K filed on September 28, 2021)
10.1	Amended and Restated Credit Agreement, dated July 20, 2021, by and among Green Plains Operating Company LLC, as the Borrower, the guarantors identified therein, TMI Trust Company, as Administrative Agent and the other lenders party thereto. (The exhibits and schedules to the Amended Credit Facility have been omitted. The Company will furnish such schedules to the SEC upon request.) (incorporated herein by reference to Exhibit 10.1 to the company’s Current Report on Form 8-K filed on July 26, 2021)
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 Inc.’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2021, formatted in Inline Extensible Business Reporting Language (iXBRL): (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
104	The cover page from Green Plains Inc.’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2021, formatted in iXBRL.

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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 4, 2021	GREEN PLAINS INC. (Registrant) By: /s/ Todd A. Becker _ Todd A. Becker ‎President and Chief Executive Officer (Principal Executive Officer)
‎ ‎ ‎Date: November 4, 2021	By: /s/ G. Patrich Simpkins Jr. _ G. Patrich Simpkins Jr. ‎Chief Financial Officer (Principal Financial Officer)

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