Renewable Energy Group, Inc. - Quarter Report: 2014 March (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q



ý	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the Quarterly Period Ended March 31, 2014



¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission File Number 001-35397

RENEWABLE ENERGY GROUP, INC.

(Exact name of registrant as specified in its charter)



Delaware		26-4785427
(State of other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

416 South Bell Avenue Ames, Iowa		50010
(Address of principal executive offices)		(Zip code)

(515) 239-8000

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15 (d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. YES ý NO ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data file required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). YES ý NO ¨

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



Large accelerated filer ¨		Accelerated filer x

Non-accelerated filer ¨		Smaller reporting company ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). YES ¨ NO ý

As of April 30, 2014, the registrant had 38,788,076 shares of Common Stock issued and outstanding.

PART I. FINANCIAL INFORMATION

ITEM 1. CONDENSED CONSOLIDATED FINANCIAL INFORMATION

RENEWABLE ENERGY GROUP, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(unaudited)

(in thousands, except share and per share amounts)



	March 31, 2014			December 31, 2013
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	76,224		$	153,227
Marketable securities	59,838			—
Accounts receivable, net (includes amounts owed by related parties of $354 and $426, respectively)	31,014			82,911
Inventories	94,075			85,814
Prepaid expenses and other assets	29,425			25,568
Total current assets	290,576			347,520
Property, plant and equipment, net	306,461			286,044
Property, plant and equipment, net - variable interest entity	5,123			5,180
Goodwill	119,710			84,864
Intangible assets, net	20,841			4,867
Other assets (includes amounts owed by related parties of $0 and $35, respectively)	12,657			12,380
TOTAL ASSETS	$	755,368		$	740,855
LIABILITIES AND EQUITY
CURRENT LIABILITIES:
Revolving line of credit	$	2,437		$	10,986
Current maturities of notes payable	7,318			6,729
Current maturities of notes payable—variable interest entity	300			300
Accounts payable (includes amounts owed to related parties of $380 and $552, respectively)	44,165			48,727
Accrued expenses and other liabilities	7,162			12,305
Deferred income taxes	2,664			3,687
Deferred revenue	11,844			15,503
Total current liabilities	75,890			98,237
Unfavorable lease obligation	7,623			7,905
Deferred income taxes	5,227			2,691
Contingent consideration for acquisition	15,706			—
Notes payable	21,900			23,422
Notes payable - variable interest entity	3,656			3,729
Other liabilities	5,275			6,838
Total liabilities	135,277			142,822
COMMITMENTS AND CONTINGENCIES (Note 15)
Series B preferred stock ($.0001 par value; 3,000,000 shares authorized; 0 and 143,313 shares outstanding; redemption amount $0 and $3,583, respectively)	—			3,963
EQUITY:
Common stock ($.0001 par value; 300,000,000 shares authorized; 38,788,076 and 36,506,221 shares outstanding, respectively)	4			4
Common stock—additional paid-in-capital	387,765			359,671
Warrants—additional paid-in-capital	147			147
Retained earnings	236,113			238,134
Accumulated other comprehensive loss	(52		)	—
Treasury stock (530,898 and 530,898 shares outstanding, respectively)	(3,886		)	(3,886		)
Total stockholders’ equity	620,091			594,070
TOTAL LIABILITIES AND EQUITY	$	755,368		$	740,855

See notes to condensed consolidated financial statements.

RENEWABLE ENERGY GROUP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(unaudited)

(in thousands, except share and per share amounts)



	Three months ended
	March 31, 2014			March 31, 2013
REVENUES:
Biodiesel sales	$	209,122		$	119,721
Biodiesel government incentives	9,890			144,605
	219,012			264,326
Services	28			42
	219,040			264,368
COSTS OF GOODS SOLD:
Biodiesel	200,305			165,883
Biodiesel—related parties	7,146			11,730
Services	25			60
	207,476			177,673
GROSS PROFIT	11,564			86,695
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES	13,527			9,644
INCOME (LOSS) FROM OPERATIONS	(1,963		)	77,051
OTHER INCOME (EXPENSE), NET:
Other income	48			117
Interest expense	(551		)	(576		)
	(503		)	(459		)
INCOME (LOSS) BEFORE INCOME TAXES	(2,466		)	76,592
INCOME TAX BENEFIT (EXPENSE)	107			(30,189		)
NET INCOME (LOSS)	(2,359		)	46,403
PLUS—GAIN ON REDEMPTION OF PREFERRED STOCK	378			—
LESS—CHANGE IN UNDISTRIBUTED DIVIDENDS ALLOCATED TO PREFERRED STOCKHOLDERS	—			(839		)
LESS—DISTRIBUTED DIVIDENDS TO PREFERRED STOCKHOLDERS	(40		)	—
LESS—EFFECT OF PARTICIPATING PREFERRED STOCK	—			(6,510		)
LESS—EFFECT OF PARTICIPATING SHARE-BASED AWARDS	—			(619		)
NET INCOME (LOSS) ATTRIBUTABLE TO THE COMPANY’S COMMON STOCKHOLDERS	$	(2,021	)	$	38,435
NET INCOME (LOSS) PER SHARE ATTRIBUTABLE TO COMMON STOCKHOLDERS:
BASIC	$	(0.05	)	$	1.25
DILUTED	$	(0.06	)	$	1.25
WEIGHTED AVERAGE SHARES USED TO COMPUTE NET INCOME (LOSS) PER SHARE ATTRIBUTABLE TO COMMON STOCKHOLDERS:
BASIC	38,290,404			30,639,284
DILUTED	38,557,441			36,628,662

See notes to condensed consolidated financial statements.

RENEWABLE ENERGY GROUP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(unaudited)

(in thousands)



	Three months ended
	March 31, 2014			March 31, 2013
Net income (loss)	$	(2,359	)	$	46,403
Unrealized losses on marketable securities, net of taxes of $0 and $0, respectively	(52		)	—
Reclassification adjustment for realized losses on marketable securities include in net income (loss), net of taxes of $0 and $0, respectively	—			—
Other comprehensive loss	(52		)	—
Comprehensive income (loss)	$	(2,411	)	$	46,403

See notes to condensed consolidated financial statements.

RENEWABLE ENERGY GROUP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF REDEEMABLE PREFERRED STOCK AND EQUITY

(unaudited)

(in thousands except share amounts)



						Company Stockholders’ Equity
	Redeemable Preferred Stock Shares		Redeemable Preferred Stock			Common Stock Shares	Common Stock		Common Stock - Additional Paid-in Capital		Warrants - Additional Paid-in Capital		Retained Earnings			Accumulated Other Comprehensive Loss			Cost of Treasury Stock			Total
BALANCE, January 1, 2013	2,995,106		$	83,043		30,559,935	$	3	$	273,989	$	147	$	53,823		$	—		$	(3,198	)	$	324,764
Issuance of common stock	—		—			58,501	—		423		—		—			—			—			423
Conversion of Series B Preferred Stock to common stock	(1,140	)	(32		)	2,300	—		32		—		—			—			—			32
Conversion of restricted stock units to common stock (net of 21,675 shares of treasury stock purchased)	—		—			28,325	—		—		—		—			—			(158		)	(158		)
Stock compensation expense	—		—			—	—		1,356		—		—			—			—			1,356
Net income	—		—			—	—		—		—		46,403			—			—			46,403
BALANCE, March 31, 2013	2,993,966		$	83,011		30,649,061	$	3	$	275,800	$	147	$	100,226		$	—		$	(3,356	)	$	372,820
BALANCE, January 1, 2014	143,313		$	3,963		36,506,221	$	4	$	359,671	$	147	$	238,134		$	—		$	(3,886	)	$	594,070
Issuance of common stock	—		—			49,662	—		582		—		—			—			—			582
Conversion of Series B Preferred Stock to common stock	(816	)	(23		)	1,634	—		23		—		—			—			—			23
Preferred stock redemption	(142,497	)	(3,940		)	—	—		—		—		378			—			—			378
Issuance of common stock in acquisition	—		—			2,230,559	—		26,254		—		—			—			—			26,254
Stock compensation expense	—		—			—	—		1,235		—		—			—			—			1,235
Net change in unrealized losses on marketable securities	—		—			—	—		—		—		—			(52		)	—			(52		)
Series B Preferred Stock dividends paid	—		—			—	—		—		—		(40		)	—			—			(40		)
Net loss	—		—			—	—		—		—		(2,359		)	—			—			(2,359		)
BALANCE, March 31, 2014	—		$	—		38,788,076	$	4	$	387,765	$	147	$	236,113		$	(52	)	$	(3,886	)	$	620,091

See notes to condensed consolidated financial statements.

RENEWABLE ENERGY GROUP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited)

(in thousands)



	Three months ended
	March 31, 2014			March 31, 2013
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$	(2,359	)	$	46,403
Adjustments to reconcile net income (loss) to net cash flows from operating activities:
Depreciation expense	3,004			2,080
Amortization expense of assets and liabilities, net	(121		)	(132		)
Provision for doubtful accounts	(150		)	(304		)
Stock compensation expense	1,235			1,356
Deferred tax expense (benefit)	(387		)	2,539
Changes in asset and liabilities, net of effects from acquisitions:
Accounts receivable, net	52,213			(153,421		)
Inventories	(8,261		)	(44,307		)
Prepaid expenses and other assets	(3,734		)	(2,872		)
Accounts payable	(7,383		)	88,801
Accrued expenses and other liabilities	(5,578		)	24,369
Deferred revenue	(3,659		)	1,361
Net cash flows provided by (used in) operating activities	24,820			(34,127		)
CASH FLOWS FROM INVESTING ACTIVITIES:
Cash paid for marketable securities	(59,975		)	—
Cash paid for purchase of property, plant and equipment	(12,773		)	(9,923		)
Cash paid for LS9 asset acquisition	(15,275		)	—
Other investing activities	112			(58		)
Net cash flows used in investing activities	(87,911		)	(9,981		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on line of credit	300,186			228,629
Repayments on line of credit	(308,735		)	(201,192		)
Cash paid on note payable	(1,006		)	(790		)
Cash paid for debt issuance costs	(118		)	(44		)
Cash paid for equity issuance costs	(108		)	(21		)
Cash paid for treasury stock	(529		)	(282		)
Cash paid for preferred stock dividends	(40		)	—
Cash paid for redemption of preferred stock	(3,562		)	—
Net cash flows provided from (used in) financing activities	(13,912		)	26,300
NET CHANGE IN CASH AND CASH EQUIVALENTS	(77,003		)	(17,808		)
CASH AND CASH EQUIVALENTS, Beginning of period	153,227			66,785
CASH AND CASH EQUIVALENTS, End of period	$	76,224		$	48,977

(continued)

RENEWABLE ENERGY GROUP, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited)

(in thousands)



	Three months ended
	March 31, 2014		March 31, 2013
SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION:
Cash received for income taxes	$	40	$	2,132
Cash paid for interest	$	539	$	345
SUPPLEMENTAL DISCLOSURE OF NON-CASH INVESTING AND FINANCING ACTIVITIES:
Amounts included in period-end accounts payable for:
Purchases of property, plant and equipment	$	4,579	$	3,782
Debt issuance cost	$	63	$	3
Incentive stock liability for raw material supply agreement	$	101	$	84
Equity issuance costs	$	321
Issuance of common stock for acquisition	$	26,254
Contingent consideration for acquisition	$	17,050
Gain on redemption of preferred stock	$	378

(concluded)

See notes to condensed consolidated financial statements.

RENEWABLE ENERGY GROUP, INC.

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

For The Three Months Ended March 31, 2014 and 2013

(unaudited)

(in thousands, except share and per share amounts)

NOTE 1 — BASIS OF PRESENTATION AND NATURE OF THE BUSINESS

The condensed consolidated financial statements have been prepared by Renewable Energy Group, Inc. and its subsidiaries (the Company), pursuant to the rules and regulations of the U.S. Securities and Exchange Commission (SEC). Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States of America (GAAP) have been condensed or omitted as permitted by such rules and regulations. All adjustments, consisting of normal recurring adjustments, have been included. Management believes that the disclosures are adequate to present fairly the financial position, results of operations and cash flows at the dates and for the periods presented. It is suggested that these interim financial statements be read in conjunction with the consolidated financial statements and the notes thereto appearing in the Company’s latest annual report on Form 10-K. Results for interim periods are not necessarily indicative of those to be expected for the fiscal year.

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts and related disclosures. Actual results could differ from those estimates.

On January 22, 2014, REG Life Sciences, LLC, a wholly-owned subsidiary of the Company, acquired substantially all of the assets and certain liabilities of LS9, Inc. (LS9) as part of its strategy to expand into the production of renewable chemicals, additional advanced biofuels and other products. LS9 was a development stage company focused on researching and developing technology to harness the power of microbial fermentation to develop and produce renewable chemicals, fuels and other products.

The biodiesel industry and the Company’s business have benefited from certain federal and state incentives. The federal biomass-based diesel mixture excise tax credit (BTC) expired on December, 31 2013 and it is uncertain whether it will be reinstated. This expiration, along with other amendments of any one or more of those laws or incentives, could adversely affect the financial results of the Company.

NOTE 2 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

We have disclosed a summary of the Company's significant accounting policies in the December 31, 2013 Annual Report on Form 10-K. There have been no material changes from the policies previously disclosed other than those noted below.

Marketable Securities

The Company’s marketable securities are classified as available-for-sale and are reported at fair value, with unrealized gains and losses, net of tax, recorded in accumulated other comprehensive income (loss). Realized gains or losses and declines in value judged to be other-than-temporary, if any, on available-for-sale securities are reported in other income, net. The Company evaluates the investments periodically for possible other-than-temporary impairment. A decline of fair value below amortized costs of debt securities is considered an other-than-temporary impairment if the Company has the intent to sell the security or it is more likely than not that the Company will be required to sell the security before recovery of the entire amortized cost basis. In those instances, an impairment charge equal to the difference between the fair value and the amortized cost basis is recognized in earnings. Regardless of the Company’s intent or requirement to sell a debt security, an impairment is considered other-than-temporary if the Company does not expect to recover the entire amortized cost basis; in those instances, a credit loss equal to the difference between the present value of the cash flows expected to be collected based on credit risk and the amortized cost basis of the debt security is recognized in earnings. The Company has no current requirement or intent to sell a material portion of marketable securities as of March 31, 2014. The Company expects to recover up to (or beyond) the initial cost of investment for securities held. In computing realized gains and losses on available-for-sale securities, the Company determines cost based on amounts paid, including direct costs such as commissions to acquire the security, using the specific identification method. During the three months ended March 31, 2014 and 2013, respectively, gross realized gains and losses on available-for-sale securities were not material.

Contingent Consideration for Acquisitions

The contingent consideration for acquisition liability was established at the time of acquisition of LS9 and is adjusted to fair value at each reporting period (See Note 3 - Acquisition of LS9, Inc.). The change in fair value is included in selling, general and administrative expense on the Condensed Consolidated Statements of Operations and was not material for the three months ended March 31, 2014.

Research and Development Costs

Research and development (R&D) costs are charged to expense as incurred. R&D expense was $1,873 and $60 for the three month ended March 31, 2014 and 2013, respectively. In process research and development (IPR&D) assets acquired in connection with the acquisition of LS9 are recorded on the Condensed Consolidated Balance Sheets as intangible assets. Acquired IPR&D is initially assigned an indefinite life and is subject to impairment testing until the completion or abandonment of the associated R&D efforts. If abandoned, the carrying value of the IPR&D asset is expensed. Once the associated R&D efforts are completed, the carrying value of the IPR&D is reclassified as a finite-lived asset and is amortized over its useful life.

Redeemable Preferred Stock

In March 2014, the Company redeemed all outstanding shares of Series B Preferred Stock. No shares of Series B Preferred Stock remain outstanding at March 31, 2014.

New Accounting Standards

In the first quarter of 2014, the Company adopted ASU 2013-11, Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists. This ASU requires unrecognized tax benefits to be presented as a reduction to deferred tax assets for net operating loss carryforwards. The adoption did not have a material impact to the Company’s financial position, results of operations or cash flows.

NOTE 3 — ACQUISITION OF LS9, INC.

On January 22, 2014, REG Life Sciences, LLC, a wholly-owned subsidiary of the Company, acquired substantially all of the assets and certain liabilities of LS9. The Company has not completed its initial accounting for this business combination as the valuation of the contingent consideration, in-process research & development intangible assets and goodwill acquired has not been finalized. The following table summarizes the consideration paid for LS9 and the amounts of assets acquired and liabilities assumed at the acquisition date:



	January 22, 2014
Consideration at fair value:
Cash	$	15,275
Common stock	26,254
Contingent consideration	17,050
Total	$	58,579



	January 22, 2014
Assets (liabilities) acquired:
Property, plant and equipment	$	8,215
In-process research & development intangible assets	15,956
Goodwill	34,846
Other noncurrent liabilities	(438		)
Total	$	58,579

The fair value of the 2,230,559 Common Stock issued as part of the consideration paid for LS9 was determined on the basis of the closing market price of the Company's common shares at the date of acquisition.

Subject to achievement of certain milestones related to the development and commercialization of products from LS9’s technology, LS9 may receive contingent consideration of up to $21,500 (Earnout Payments) over a five-year period. The Earnout Payments will be payable in cash, the Company's stock or a combination of cash and stock at the Company's election. The portion of contingent consideration estimated to be paid within twelve months is $1,344 and is included in accrued expenses on the condensed consolidated balance sheet.

The goodwill acquired is included in the biodiesel segment, is expected to be deductible for tax purposes and arises largely from the synergies and certain intangible assets that do not qualify for separate recognition.

The amounts of LS9's revenue and earnings included in our consolidated income statement for the three months ended March 31, 2014 and the revenue and earnings of the combined entity had the acquisition date been January 1, 2013, are as follows:



	Revenue		Net Income			Basic Net Income Per Share
Actual from 1/22/2014 - 3/31/2014	$	—	$	(1,843	)	N/A
2014 supplemental pro forma from 1/1/2014 - 3/31/2014	219,061		(2,644		)	(0.06	)
2013 supplemental pro forma from 1/1/2013 - 3/31/2013	264,403		43,350			1.11

NOTE 4 — MARKETABLE SECURITIES

The Company's investments in marketable securities are stated at fair value and are available for sale. The following tables summarizes the Company's marketable securities:



	As of March 31, 2014
	Maturity	Gross Amortized Cost		Fair Value		Total Unrealized Losses
Commercial paper	Within one year	$	26,950	$	26,947	$	(3	)
Corporate bonds	Within one year	25,541		25,508		(33		)
Certificates of deposit	Within one year	7,399		7,383		(16		)
Total		$	59,890	$	59,838	$	(52	)

NOTE 5 — INVENTORIES

Inventories consist of the following:



	March 31, 2014		December 31, 2013
Raw materials	$	15,039	$	13,393
Work in process	1,407		1,456
Finished goods	77,629		70,965
Total	$	94,075	$	85,814

NOTE 6 — PREPAID EXPENSES AND OTHER ASSETS

Prepaid expense and other assets consist of the following:



	March 31, 2014		December 31, 2013
Commodity derivatives and related collateral, net	$	12,981	$	13,675
Prepaid expenses	2,949		2,414
Deposits	4,241		293
RIN inventory	6,650		6,455
Income taxes receivable	2,138		2,197
Other	466		534
Total	$	29,425	$	25,568

RIN inventory values were adjusted in the amount of $579 and $1,277 at March 31, 2014 and December 31, 2013, respectively, to reflect the lower of cost or market.

NOTE 7 — GOODWILL

The following table shows the carrying amount of goodwill by reportable segment as of December 31, 2013 and the changes in goodwill for the three month period ended March 31, 2014:



	Biodiesel		Services		Total
Balance, December 31, 2013	$	68,784	$	16,080	$	84,864
Acquisitions	34,846		—		34,846
Balance, March 31, 2014	$	103,630	$	16,080	$	119,710

NOTE 8 — INTANGIBLE ASSETS

Intangible assets consist of the following:



	As of March 31, 2014
	Cost		Accumulated Amortization			Net
Raw material supply agreement	$	5,603	$	(833	)	$	4,770
Ground lease	200		(85		)	115
Total amortizing intangibles	5,803		(918		)	4,885
In-process research and development, indefinite lives	15,956		—			15,956
Total intangible assets	$	21,759	$	(918	)	$	20,841



	As of December 31, 2013
	Cost		Accumulated Amortization			Net
Raw material supply agreement	$	5,502	$	(753	)	$	4,749
Ground lease	200		(82		)	118
Total amortizing intangibles	5,702		(835		)	4,867
In-process research and development, indefinite lives	—		—			—
Total intangible assets	$	5,702	$	(835	)	$	4,867

The estimated intangible asset amortization expense for fiscal year 2014 through fiscal year 2018 is as follows:



April 1, 2014 through December 31, 2014	$	335
2015	479
2016	492
2017	506
2018	521
2019 and thereafter	2,552

NOTE 9 — BORROWINGS

The Company’s notes payable are as follows:



	March 31, 2014		December 31, 2013
REG Danville term loan	$	5,326	$	5,626
REG Newton term loan	17,514		18,143
REG Mason City term loan	5,135		5,135
Other	1,243		1,247
Total notes payable	$	29,218	$	30,151
Bell, LLC promissory note—variable interest entity	$	3,956	$	4,029

REG Danville, LLC (REG Danville) has a term loan agreement with Fifth Third Bank (Danville Loan) which will mature in November 2015. The Danville Loan requires monthly principal payments of $150 and interest based on a rate of LIBOR plus 5% per annum (5.15% at March 31, 2014). The Danville Loan is secured by the Danville facility and contains various loan covenants that restrict REG Danville’s ability to take certain actions, including prohibiting it from making payments to the Company in certain situations. The Danville Loan also requires semi-annual payments equal to 50% of its Excess Cash Flow which is defined as REG Danville’s EBITDA plus certain affiliate payments, less principal payments, interest expense, taxes and capital expenditures. The excess cash flow payment required for the second half of 2013 was $1,350 and was paid in April 2014. The Company recorded an estimated excess cash flow payment required the three months ended March 31, 2014 of $346.

REG Newton, LLC (REG Newton) has a term loan agreement AgStar Financial Services, PCA (Newton Loan) which will mature in December 2018. The Newton Loan is secured by all plant assets owned by REG Newton. Interest is to be accrued based on 30-day LIBOR plus 400 basis points (4.16% at March 31, 2014). REG Newton is required to make monthly principal and interest payments of $270. The Newton Loan agreement requires REG Newton to make an annual payment equal to 50% of its Excess Cash Flow which is defined as REG Newton's EBITDA, less the sum of required debt payments, interest expense, up to $750 in maintenance capital expenditure and allowed distributions. There was no required excess cash flow payment required for 2013 or the three months ended March 31, 2014.

REG Mason City, LLC (REG Mason City) has a term loan agreement with Soy Energy, LLC (Mason City Loan) which will mature in July 2019. The Mason City loan requires interest only payments for the first eight months and monthly principal and interest payments of approximately $92 starting in April 2014. Interest is based on a fixed rate of 5%. The Mason City Loan is secured by the Mason City Facility and contains a covenant that restricts REG Mason City’s ability to take certain actions, including prohibiting it from making payments to the Company in certain circumstances. The Mason City Loan requires annual excess cash flow payments equal to 50% of its excess cash flow. There was no required excess cash flow payment required for 2013 or the three months ended March 31, 2014.

Revolving Line of Credit



	March 31, 2014		December 31, 2013
Amount borrowed under revolving line of credit	$	2,437	$	10,986
Maximum available to be borrowed under revolving line of credit	$	20,938	$	29,014

The Company, through two of its subsidiaries, has a revolving credit facility with a bank group (the Wells Fargo Revolver) which matures in December 2016. The agreement provides for loans up to $40,000 based on eligible collateral. The loans bear interest at (a) LIBOR plus a margin ranging from 2.50% to 3.25% or (b) the greatest of (i) 1.75% per annum, (ii) the Federal Funds Rate plus 0.5%, (iii) the LIBOR Rate plus 1.5%, or (iv) the “prime rate” plus 1.00% to 1.75%. The effective interest rate was 3.75% at March 31, 2014.

The Wells Fargo Revolver contains various loan covenants that restrict each subsidiary borrower’s ability to take certain actions, including restrictions on incurrence of indebtedness, creation of liens, mergers or consolidations, dispositions of assets, repurchase or redemption of capital stock, making certain investments, entering into certain transactions with affiliates or changing the nature of the subsidiary’s business. In addition, the subsidiary borrowers are required to maintain a Fixed Charge Coverage Ratio (as defined) of at least 1.0 to 1.0 and to have Excess Availability (as defined) of at least $4,000. The revolving credit facility is secured by the subsidiary borrowers’ membership interests and substantially all of their assets, and the inventory of certain subsidiaries, subject to a $25,000 limitation.

NOTE 10 — RELATED PARTY TRANSACTIONS

West Central Cooperative

West Central beneficially owns more than 5% of our outstanding securities. The Company has several contractual relationships and transactions with West Central, including contracts for services, supply of soybean oil feedstock, a ground lease for the Ralston facility and an extended payment terms arrangement

Under the ground lease with West Central, West Central leases the real property on which the Ralston facility is located for an annual rental fee of one dollar. The ground lease has a 20-year term ending July 31, 2026 and the Company may elect to extend the term for six additional five-year terms. The Company also has an Asset Use Agreement with West Central which provides for the use of certain assets, such as buildings, equipment and utilities, which will be charged to the Company based on fixed and variable components.

The Company purchases once-refined soybean oil from West Central to supply the Ralston facility. On October 1, 2012, the Company entered into a new feedstock supply agreement with West Central. The supply agreement is for a sixteen month period with the option for a one year extension. West Central agrees to supply and the Company agrees to purchase soybean oil for the Ralston facility at a price indexed to prevailing Chicago Board of Trade, or CBOT, soybean oil market prices with an agreed upon negotiated market basis.

In June 2009, the Company entered into an extended payment terms agreement with West Central. The agreement set forth the terms of payment that apply for soybean oil that West Central sold to the Company for use at the Ralston facility, as well as any other feedstock that West Central agreed to sell. Pursuant to the agreement, payment for feedstocks delivered by West Central is required to be made within 45 days after delivery by West Central of an invoice for the feedstocks. Interest accrues on amounts due for feedstocks supplied by West Central beginning on the fifth day after West Central delivered an invoice for the feedstock until paid. At no time during the term of the agreement is the amount payable to West Central permitted to exceed $3,000. The agreement expires in January 2015 and automatically renews for one additional year unless either party provides sufficient notice of cancellation prior to the renewal.




	Three Months Ended March 31, 2014		Three Months Ended March 31, 2013
Cost of goods sold – Biodiesel	$	7,146	$	11,730
Selling, general and administrative expenses	$	—	$	2
Interest expense	$	—	$	20




	As of March 31, 2014		As of December 31, 2013
Accounts receivable	$	354	$	426
Other assets	$	—	$	35
Accounts payable	$	380	$	552

NOTE 11 — DERIVATIVE INSTRUMENTS

The Company enters into heating oil and soybean oil futures, swaps and options (commodity contract derivatives) to hedge its exposure to price risk related to anticipated purchases of feedstock raw materials and to protect gross profit margins from potentially adverse effects of price volatility on biodiesel sales where prices are set at a future date. All of the Company’s commodity contract derivatives are designated as non-hedge derivatives and recorded at fair value on the condensed consolidated balance sheet. Unrealized gains and losses are recognized as a component of biodiesel costs of goods sold reflected in current results of operations. As of March 31, 2014, the Company had 1,239 open commodity contracts.

The Company offsets the fair value amounts recognized for its commodity contract derivatives with cash collateral with the same counterparty under a master netting agreement. The net position is presented within prepaid and other assets in the condensed consolidated balance sheet. The following table sets forth the fair value of the Company's commodity contract

derivatives and amounts that offset within the condensed consolidated balance sheet:



	March 31, 2014						December 31, 2013
	Assets			Liabilities			Assets			Liabilities
Gross amounts of derivatives recognized at fair value	$	1,064		$	371		$	325		$	546
Cash collateral	12,288			—			13,896			—
Total gross amount recognized	13,352			371			14,221			546
Gross amounts offset	(371		)	(371		)	(546		)	(546		)
Net amount reported in the condensed consolidated balance sheet	$	12,981		$	—		$	13,675		$	—

The following table sets forth the pre-tax gains (losses) included in the condensed consolidated statement of operations:



	Location of Gain (Loss) Recognized in income	Three Months Ended March 31, 2014			Three Months Ended March 31, 2013
Commodity contracts	Cost of goods sold – Biodiesel	$	(694	)	$	1,367

NOTE 12 — FAIR VALUE MEASUREMENT

The fair value hierarchy prioritizes the inputs used in measuring fair value as follows:


•	Level 1 — Quoted prices for identical instruments in active markets.


•	Level 2 — Quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active and model-derived valuations, in which all significant inputs are observable in active markets.


•	Level 3 — Unobservable inputs in which there is little or no market data, which require the reporting entity to develop its own assumptions.

A summary of assets (liabilities) measured at fair value is as follows:



	As of March 31, 2014
	Total			Level 1		Level 2		Level 3
Money market funds	$	1,801		$	1,801	$	—	$	—
Marketable securities:
Certificates of deposit	7,383			—		7,383		—
Commercial paper	26,947			—		26,947		—
Commercial notes/bonds	25,508			—		25,508		—
Commodity contract derivatives	693			—		693		—
Contingent consideration for acquisition	(17,050		)	—		—		(17,050		)



	As of December 31, 2013
	Total			Level 1		Level 2			Level 3
Commodity contract derivatives	$	(221	)	$	—	$	(221	)	$	—

The following is a reconciliation of the beginning and ending balances for liabilities measured at fair value on a recurring basis using significant unobservable inputs (Level 3) during the three months ended March 31, 2014:



Contingent consideration for acquisition	Three months ended March 31, 2014
Balance at beginning of the period	$	—
Additions for acquisition	17,050
Balance at end of period	$	17,050

The estimated fair values of the Company’s financial instruments, which are not recorded at fair value, are as follows:



	As of March 31, 2014						As of December 31, 2013
	Asset (Liability) Carrying Amount			Fair Value			Asset (Liability) Carrying Amount			Fair Value
Financial liabilities:
Notes payable and lines of credit	$	(35,611	)	$	(35,537	)	$	(45,166	)	$	(45,094	)

The carrying amounts reported in the Condensed Consolidated Balance Sheets for cash and cash equivalents, accounts receivable, accounts payable and accrued expenses approximate their fair values. Money market funds are included in cash and cash equivalents on the Condensed Consolidated Balance Sheets.

The Company used the following methods and assumptions to estimate fair value of its financial instruments:

Marketable securities: The fair value of marketable securities are obtained using quoted prices for similar assets or liabilities in active markets; quoted prices for identical or similar assets in markets that are not active; and inputs other than quoted prices, e.g., interest rates and yield curves. The Company utilizes a pricing service to assist in obtaining fair value pricing for the majority of this investment portfolio.

Commodity derivatives: The instruments held by the Company consist primarily of futures contracts, swap agreements, purchased put options and written call options. The fair value is determined based on quoted prices of similar contracts in over-the-counter markets and are reflected in Level 2.

Contingent consideration for acquisitions: The fair value of this contingent consideration is determined using an expected present value technique. Expected cash flows are determined using the probability weighted-average of possible outcomes that would occur should achievement of certain milestones related to the development and commercialization of products from LS9’s technology occur. There is no observable market data available to use in valuing the contingent consideration; therefore, the Company developed its own assumptions related to the expected future delivery of product enhancements to estimate the fair value of these liabilities. An 8% discount rate is used to estimate the fair value of the expected payments.

Notes payable and lines of credit: The fair value of long-term debt and lines of credit was established using discounted cash flow calculations and current market rates reflecting Level 2 inputs.

NOTE 13 — NET INCOME (LOSS) PER SHARE

Basic net income (loss) per common share is presented in conformity with the two-class method required for participating securities. Participating securities include, or have included, Series B Preferred Stock and RSU's.

Under the two-class method, net income is reduced for distributed and undistributed dividends earned in the current period. The remaining earnings are then allocated to common stock and the participating securities. The Company calculates the effects of participating securities on diluted earnings per share (EPS) using both the “if-converted or treasury stock” and "two-class" methods and discloses the method which results in a more dilutive effect. The effects of Common Stock options, warrants, and stock appreciation rights on diluted EPS are calculated using the treasury stock method unless the effects are anti-dilutive to EPS.

The following potentially dilutive weighted average securities were excluded from the calculation of diluted net income (loss) per share attributable to common stockholders during the periods presented as the effect was anti-dilutive:



	Three Months Ended March 31, 2014	Three Months Ended March 31, 2013
Options to purchase common stock	87,026	87,026
Restricted stock units	567,716	504,666
Stock appreciation rights	1,583,670	1,073,385
Warrants to purchase common stock	17,916	17,916
Total	2,256,328	1,682,993

The following table presents the calculation of diluted net income (loss) per share:



	Three Months Ended March 31, 2014			Three Months Ended March 31, 2013
Net income (loss) attributable to the Company’s common stockholders - Basic	$	(2,021	)	$	38,435
Plus: change in undistributed dividends allocated to preferred stockholders	—			839
Plus: distributed dividends to Preferred Stockholders	40			—
Plus (Less): effect of participating securities	(378		)	6,498
Net income (loss) available to common stockholders - Dilutive	(2,359		)	45,772
Shares:
Weighted-average shares used to compute basic net income (loss) per share	38,290,404			30,639,284
Adjustment to reflect conversion of preferred stock	267,037			5,989,378
Weighted-average shares used to compute diluted net income (loss) per share	38,557,441			36,628,662
Net income (loss) per share attributable to common stockholders
Diluted	$	(0.06	)	$	1.25

NOTE 14 — REPORTABLE SEGMENTS

The Company reports its reportable segments based on products and services provided to customers, which include Biodiesel, Services and Corporate and other activities. The accounting policies of the segments are the same as those described in the summary of significant accounting policies. The Company has chosen to differentiate the reportable segments based on the products and services each segment offers.

The Biodiesel segment processes waste vegetable oils, animal fats, virgin vegetable oils and other feedstocks and methanol into biodiesel. The Biodiesel segment also includes the Company’s purchases and resale of biodiesel produced by third parties. Revenue is derived from the purchases and sales of biodiesel and raw material feedstocks acquired from third parties, sales of biodiesel produced under toll manufacturing arrangements with third party facilities, sales of processed biodiesel from Company facilities, sales of RINs, related by-products and renewable energy government incentive payments. The Services segment offers services for managing the construction of biodiesel production facilities and managing ongoing operations of internal and third party plants and collects fees related to the services provided. The Company does not allocate items that are of a non-operating nature or corporate expenses to the business segments. Intersegment revenues are reported by the Services segment, which manages the construction and operations of facilities included in the Biodiesel segment. Revenues are recorded by the Services segment at cost. Corporate expenses consist of corporate office expenses including compensation, benefits, occupancy and other administrative costs, including management service expenses.

The following table represents the significant items by reportable segment:



	Three Months Ended March 31, 2014			Three Months Ended March 31, 2013
Net revenues:
Biodiesel	$	219,012		$	264,326
Services	20,524			13,897
Intersegment revenues	(20,496		)	(13,855		)
	$	219,040		$	264,368
Income (loss) before income taxes:
Biodiesel	$	11,561		$	86,713
Services	3			(18		)
Corporate and other (a)	(14,030		)	(10,103		)
	$	(2,466	)	$	76,592
Depreciation and amortization expense, net:
Biodiesel	$	2,589		$	1,725
Services	41			19
Corporate and other (a)	253			204
	$	2,883		$	1,948
Cash paid for purchases of property, plant and equipment:
Biodiesel	$	12,554		$	9,724
Services	—			99
Corporate and other (a)	219			100
	$	12,773		$	9,923



	As of March 31, 2014		As of December 31, 2013
Assets:
Biodiesel	$	524,440	$	444,945
Services	20,718		20,542
Corporate and other (b)	210,210		275,368
	$	755,368	$	740,855


(a)	Corporate and other includes income/(expense) not associated with the reportable segments, such as corporate general and administrative expenses, shared service expenses, interest expense and interest income.


(b)	Corporate and other includes cash and other assets not associated with the reportable segments, including investments.

NOTE 15 — COMMITMENTS AND CONTINGENCIES

On December 17, 2013, the Company and REG Synthetic Fuels, LLC (REG Synthetic Fuels), a wholly-owned subsidiary of the Company, entered into an Asset Purchase Agreement with Syntroleum Corporation (Syntroleum) to acquire substantially all assets, including all of Syntroleum's intellectual property and its 50% equity interest in Dynamic Fuels, LLC. As consideration for the asset sale, REG Synthetic Fuels will assume substantially all material assets and liabilities of Syntroleum and Syntroleum will receive 3,796,000 shares of the Company's Common Stock, subject to downward adjustment (based on the value of the Company's Common Stock at closing, as calculated under the Asset Purchase Agreement) to the extent that Syntroleum’s cash on hand at closing is less than $3,200; provided, that, if the per share value of the Company’s Common Stock at closing (as calculated under the Asset Purchase Agreement) is equal to or greater than $12.91, then the number of shares of the Company's Common Stock will be equal to (i) $49,000, divided by (ii) the Company's Common Stock value at closing (as calculated under the Asset Purchase Agreement). The closing of the transaction is conditioned upon Syntroleum’s receipt of the approval of the holders of a majority of Syntroleum’s outstanding shares of common stock and other specified closing conditions. On June 3, 2014, the shareholders of Syntroleum Corporation will hold a vote to approve our agreement to purchase substantially all the assets of Syntroleum, including 50% ownership interest in Dynamic Fuels, a 75-million gallon renewable diesel refinery located in Giesmar, Louisiana, and an extensive patent portfolio of gas-to-liquids and renewable fuel technologies. We expect to close the transaction shortly thereafter. Accordingly, this transaction is not reflected in the Company's financial statements as of March 31, 2014.

The Company is involved in legal proceedings in the normal course of business. The Company currently believes that any ultimate liability arising out of such proceedings will not have a material adverse effect on the Company’s financial position, results of operations or cash flows.

NOTE 16 — SUBSEQUENT EVENTS

The Company has performed an evaluation of subsequent events through the date the financial statements were issued and has determined there have been no material subsequent events requiring disclosure.

* * * * * *



ITEM 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

This report contains forward-looking statements regarding Renewable Energy Group, Inc., or “we,” “our” or “the Company” that involve risks and uncertainties such as anticipated financial performance, business prospects, technological developments, products, possible strategic initiatives and similar matters. In some cases, you can identify forward-looking statements by terms such as “may,” “might,” “objective,” “intend,” “should,” “could,” “can,” “would,” “expect,” “believe,” “estimate,” “predict,” “potential,” “plan,” or the negative of these terms, and similar expressions intended to identify forward-looking statements.

These forward-looking statements include, but are not limited to, statements about facilities currently under development progressing to the construction and operational stages, including planned capital expenditures and our ability to obtain financing for such construction; existing or proposed legislation affecting the biodiesel industry, including governmental incentives and tax credits; our utilization of forward contracting and hedging strategies to minimize feedstock and other input price risk; anticipated future revenue sources from our operational management and facility construction services; the expected effect of current and future environmental laws and regulations on our business and financial condition; our ability to renew existing and expired contracts at similar or more favorable terms; expected technological advances in biodiesel production methods; our competitive advantage relating to input costs relative to our competitors; the market for biodiesel and potential biodiesel consumers; our ability to further develop our financial, managerial and other internal controls and reporting systems to accommodate future growth; expectations regarding the realization of deferred tax assets and the establishment and maintenance of tax reserves and anticipated trends; expectations regarding our expenses and sales; anticipated cash needs and estimates regarding capital requirements and needs for additional financing; and challenges in our business and the biodiesel market.

These forward-looking statements are based on management’s current expectations, estimates, assumptions and projections, which are subject to risks and uncertainties. These risks and uncertainties could cause actual results to differ materially from those expected. Given these uncertainties, you should not place undue reliance on these forward-looking statements. Risks and uncertainties include, but are not limited to, those risks discussed in Item 1A Part II in this Quarterly Report on Form 10-Q for the three-months ended March 31, 2014. We encourage you to read this Management’s Discussion and Analysis of Financial Condition and Results of Operations in conjunction with the accompanying condensed consolidated financial statements and related notes. Forward-looking statements contained in this report present management’s views only as of the date of this report. Except as required under applicable law, we do not intend to issue updates concerning any future revisions of management’s views to reflect events or circumstances occurring after the date of this report.

Overview

We intend to become a leading producer of advanced biofuels and renewable chemicals. We are currently the largest producer of biodiesel, an advanced biofuel, in the United States based on gallons produced. We participate in each aspect of biodiesel production, from acquiring feedstock, managing construction and operating biodiesel production facilities to marketing, selling and distributing biodiesel and its co-products.

We operate a network of eight operational biodiesel plants, with an aggregate nameplate production capacity of 257 million gallons per year, or mmgy. We have acquired six of our eight facilities since February 2010. We believe our fully integrated approach, which includes acquiring feedstock, managing biorefinery facility construction and upgrades, operating biorefineries, marketing renewable products and distributing through a network of terminals, positions us to capitalize on growing demand for biodiesel, renewable chemicals and other advanced biofuels. Our experience has enabled us to develop extensive expertise in biorefinery operations, from facility construction management and feedstock procurement to biodiesel production, marketing, logistics and risk management.

We are a low-cost biodiesel producer. We primarily produce our biodiesel from a wide variety of lower cost feedstocks, including inedible corn oil, used cooking oil and inedible animal fat. We also produce biodiesel from virgin vegetable oils, which are more widely available and tend to be higher in price. We believe our ability to process a wide variety of feedstocks provides us with a cost advantage over many biodiesel producers, particularly those that rely on higher cost virgin vegetable oils, such as soybean oil or canola oil.

On January 22, 2014, we acquired substantially all of the assets and certain liabilities of LS9, Inc., or LS9, as part of our strategy to expand into the production of renewable chemicals, additional advanced biofuels and other products. LS9 was a development stage company focused on harnessing the power of microbial fermentation to develop and produce renewable chemicals, fuels and other products. The assets acquired consist mainly of in-process research and development, fixed assets and goodwill.

On February 12, 2014, we announced the launch of a new division, REG Energy Services, LLC, that will sell petroleum-based heating oil and diesel fuel, and enable us to offer more biofuel blends. We will sell heating oil and ultra-low sulfur diesel,

or ULSD, at terminals initially throughout the northeastern U.S. as well as BioHeat® blended heating fuel at one of our existing terminal locations and potentially in other locations across North America.

On June 3, 2014, the shareholders of Syntroleum Corporation will hold a vote to approve our agreement to purchase substantially all the assets of Syntroleum, including 50% ownership interest in Dynamic Fuels, a 75-million gallon renewable diesel refinery located in Giesmar, Louisiana, and an extensive patent portfolio of gas-to-liquids and renewable fuel technologies. We expect to close the transaction shortly thereafter.

For the three months ended March 31 2014, we sold 47 million of biodiesel, including seven million gallons that we purchased from third parties and resold. During 2013, we sold a total of 259 million gallons of biodiesel, including 48 million gallons we purchased from third parties and resold.

We own three partially completed biodiesel production facilities and one non-operational plant. In 2007, we began construction of two 60 mmgy nameplate production capacity facilities, one near New Orleans, Louisiana and the other in Emporia, Kansas. In February 2008, we halted construction of these facilities as a result of conditions in the biodiesel industry and our inability to obtain financing necessary to complete construction of the facilities. Construction of the New Orleans facility is approximately 45% complete and construction of the Emporia facility is approximately 20% complete. Further, during the third quarter of 2010, we acquired a 15 mmgy nameplate biodiesel production capacity facility in Clovis, New Mexico which is approximately 50% complete. Currently, the Clovis facility is being operated as a terminal. In November 2012, we acquired a 15 mmgy nameplate biodiesel production facility near Atlanta, Georgia that was idled prior to our acquisition and will remain non-operational until certain repairs or upgrades are made. We plan to complete construction and upgrade of these facilities as financing becomes available, and subject to market conditions.

We derive revenues from two reportable business segments: Biodiesel and Services

Biodiesel Segment

Our Biodiesel segment, as reported herein, includes:


•	the operations of the following biodiesel production facilities:


•	a 12 mmgy nameplate biodiesel production facility located in Ralston, Iowa;


•	a 35 mmgy nameplate biodiesel production facility located near Houston, Texas;


•	a 45 mmgy nameplate biodiesel production facility located in Danville, Illinois;


•	a 30 mmgy nameplate biodiesel production facility located in Newton, Iowa;


•	a 60 mmgy nameplate biodiesel production facility located in Seneca, Illinois;


•	a 30 mmgy nameplate biodiesel production facility located near Albert Lea, Minnesota;


•	a 15 mmgy nameplate biodiesel production facility located in New Boston, Texas, since its acquisition in October 2012 that was idle prior to acquisition. We completed repairs to the facility and started producing biodiesel at the facility in June 2013;


•	a 30 mmgy nameplate biodiesel production facility located in Mason City, Iowa, since its acquisition in July 2013 that was idle prior to acquisition. We completed repairs to the facility and started producing biodiesel at the facility in October 2013;


•	purchases and resale of biodiesel, Renewable Identification Numbers, or RINs, and raw material feedstocks acquired from third parties;


•	our sales of biodiesel produced under toll manufacturing arrangements with third party facilities using our feedstocks;


•	our production of biodiesel under toll manufacturing arrangements with third parties using their feedstocks at our facilities; and


•	incentives received from federal and state programs for renewable fuels.

We derive a small portion of our revenues from the sale of glycerin, free fatty acids and other co-products of the biodiesel production process. In 2013 and the three months ended March 31, 2014, our revenues from the sale of co-products were less than five percent of our total Biodiesel segment revenues.

In accordance with EPA regulations, we generate 1.5 Renewable Identification Numbers, or RINS, for each gallon of biodiesel we produce and sell. RINs are used to track compliance with RFS2 using the EPA moderated transaction system, or EMTS. RFS2 allows us to attach between zero and 2.5 RINs to any gallon of biodiesel we sell. We generally attach 1.5 RINs when we sell a gallon of biodiesel. As a result, a portion of our selling price for a gallon of biodiesel is generally attributable to RFS2 compliance, however no cost is allocated to the RINs generated by our biodiesel production as RINs are a form of government incentive and not a result of the physical attributes of the biodiesel production. In addition, RINs, once obtained

with gallons of biodiesel, may be separated by the acquirer and sold separately. From time to time, we may obtain these RINs from third parties for resale, and the value of these is reflected in “Prepaid expenses and other assets” on our consolidated balance sheet. At each balance sheet date, this RIN inventory is valued at the lower of cost or market and resulting adjustments are reflected in our cost of goods sold for the period. The cost of RINs obtained from third parties is determined using the average cost method. Because we do not allocate costs to RINs generated by our biodiesel production, fluctuations in the value of our RIN inventory represent fluctuations in the value of RINs we have obtained from third parties.

Services Segment

Our Services segment includes:


•	biodiesel facility management and operational services, whereby we provide day-to-day management and operational services to biodiesel production facilities; and


•	construction management services, whereby we act as the construction management and general contractor for the construction of biodiesel production facilities.

Historically, we provided facility operations management services to owners of biodiesel production facilities under management and operational services agreements, or MOSAs. During 2010, we ceased providing services to three of these facilities, acquired one and continued to provide limited services to the other facility. The termination of our MOSAs has not had a significant impact on our financial statements. Our Services segment has been focused internally on managing and upgrading our facilities.

We have utilized our construction management expertise internally to upgrade our facilities. We are currently working on a $20 million upgrade to our Mason City facility and a $13 million upgrade to our Newton facility. In 2013, we completed a $22 million upgrade to our Albert Lea facility and spent $4 million and $1 million in repairs of our recently acquired New Boston and Mason City facilities, respectively. We anticipate external revenues derived from construction management services will be minimal in future periods. Demand for our construction management and facility management and operational services depend on capital spending by potential customers and existing customers, which is directly affected by trends in the biodiesel industry. We have not received any orders or provided services to outside parties for new facility construction services since 2009.

Factors Influencing Our Results of Operations

The principal factors affecting our operations are the market prices for biodiesel and the feedstocks used to produce biodiesel, as well as governmental programs designed to create incentives or requirements for the production and use of biodiesel.

Governmental programs favoring biodiesel production and use

Biodiesel has historically been more expensive than petroleum-based diesel, excluding biodiesel incentives and credits. The biodiesel industry’s growth has largely been the result of federal and state programs that require or incentivize biodiesel, which allows biodiesel to compete with petroleum-based diesel on price.

On July 1, 2010, RFS2 was implemented, stipulating volume requirements for the amount of biomass-based diesel and other advanced biofuels that must be utilized in the United States each year. Under RFS2, Obligated Parties, including petroleum refiners and fuel importers, must show compliance with these standards. Currently, biodiesel meets two categories of an Obligated Party’s annual renewable fuel required volume obligation, or RVO—biomass-based diesel and undifferentiated advanced biofuel. The RFS2 program required the domestic use of one billion gallons of biodiesel in 2012 and 1.28 billion gallons in 2013. As of this filing, the EPA has not finalized the 2014 RVO. The EPA has proposed that the 2014 and 2015 biomass-based diesel RVO be 1.28 billion gallons for each of those years and a reduced Advanced Biofuel RVO of 2.20 billion gallons rather than the original EISA volume of 3.75 billion for 2014. According to EMTS data, 0.33 billion gallons of biomass-based diesel was produced for the three months ended March 31, 2014. Since 2010, our sales volumes and revenues have benefited from our increased production capacity, as well as an increase in demand relating to the implementation of RFS2.

The 2013 RFS2 requirement for biomass-based diesel was 1.28 billion. According to EMTS data, 1.78 billion gallons of biomass-based diesel was produced in 2013. We believe more gallons were produced in 2013 than were required by RFS2 as a result of the fact that the federal biomass-based diesel mixture excise tax credit, or BTC, was set to expire on December 31, 2013. Since Obligated Parties are allowed to satisfy up to 20% of their 2014 RVO with 2013 RINs, we believe many producers, importers and purchasers of biodiesel were taking advantage of the BTC while it was available. We believe this 2013 overproduction and importation of more biodiesel in 2013 than was required to meet the 2013 RVO, when combined with the unseasonably cold winter, led to decreased demand for biodiesel in the first quarter of 2014.

The BTC provided a $1.00 refundable tax credit per gallon of 100% pure biodiesel, or B100, to the first blender of biodiesel with petroleum-based diesel fuel. The BTC expired on December 31, 2013 and it is uncertain whether it will be reinstated again. The expiration of the BTC along with any amendments that may be made if the BTC is reinstated or a similar credit is enacted, could adversely affect our financial results in the future.

Biodiesel and feedstock price fluctuations

Our operating results generally reflect the relationship between the price of biodiesel, including credits and incentives, like RINs and the price of feedstocks used to produce biodiesel.

Biodiesel is a low carbon, renewable alternative to petroleum-based diesel fuel and is primarily sold to the end user after it has been blended with petroleum-based diesel fuel. Biodiesel prices have historically been heavily influenced by petroleum-based diesel fuel prices. Accordingly, biodiesel prices have generally been impacted by the same factors that affect petroleum prices, such as worldwide economic conditions, supply and demand factors, wars and other political events, OPEC production quotas, changes in petroleum refining capacity and natural disasters.

Regulatory and legislative factors also influence the price of biodiesel. Biomass-based diesel RIN pricing, a value component that was introduced via RFS2 in July 2010, has had a significant impact on our biodiesel pricing. In December 2013, the value of RINs, as reported by OPIS, contributed approximately $0.49, or 13%, of the average B100 Upper Midwest spot price of a gallon of biodiesel as reported by The Jacobsen. During 2013, the value of RINs, as reported by OPIS, have contributed to the average B100 spot price of a gallon of biodiesel, as reported by The Jacobsen, and range from a low of $0.35 per gallon, or 9%, in October to a high of $2.20, or 43%, per gallon in January. There was a sharp decline in RIN prices during the third and fourth quarters of 2013. During this period, RIN pricing declined from $1.07 per RIN at June 30, 2013 to the low price of $0.24 per RIN in November 2013, finishing the year at $0.35 per RIN on December 31, 2013, as reported by OPIS, which contributed to the decline in average price of biodiesel during 2013. During the first three months of 2014, the value of RINs, as reported by OPIS, contributed approximately $0.84 or , or 27%, of the average B100 Upper Midwest spot price of a gallon of biodiesel, as reported by The Jacobsen.

During 2013, feedstock expense accounted for 84% of our production cost, while methanol and chemical catalysts expense accounted for 5% and 3% of our costs of goods sold, respectively.

Feedstocks for biodiesel production, such as inedible corn oil, used cooking oil, inedible animal fat and soybean oil are commodities and market prices for them will be affected by a wide range of factors unrelated to the price of biodiesel and petroleum-based diesel fuels. The following table outlines some of the factors influencing supply and price for each feedstock:



Feedstock		Factors Influencing Supply and Price
Inedible Corn Oil		Implementation of inedible corn oil separation systems into existing and new ethanol facilities
		Demand for inedible corn oil from renewable fuel and other markets
		Ethanol production
		Export demand
		Extraction system yield
Used Cooking Oil		Export demand
		Population
		Number of restaurants in the vicinity of collection facilities and terminals which is dependent on population density
		Cooking methods and eating habits, which can be impacted by the economy
Inedible Animal Fat		Export demand
		Number of slaughter kills in the United States
		Demand for inedible animal fat from other markets
Soybean Oil		Export demand
		Weather conditions
		Soybean meal demand
		Farmer planting decisions
		Government policies and subsidies
		Crop disease

During 2013, 83% of our feedstocks were comprised of inedible corn oil, used cooking oil and inedible animal fats with the remainder coming from refined vegetable oil.

Historically, most biodiesel in the United States has been made from soybean oil. Soybean oil prices have fluctuated greatly, but have generally remained at historically high levels since due to higher overall commodity prices. Over the period January 2010 to March 2014, soybean oil prices (based on daily closing nearby futures prices on the Chicago Board of Trade, or CBOT, for crude soybean oil) have ranged from $0.3584 per pound, or $2.69 per gallon of biodiesel, in July 2010 to $0.5977 per pound, or $4.48 per gallon of biodiesel, in April 2011, assuming 7.5 pounds of soybean oil yields one gallon of biodiesel. The average closing price for soybean oil during 2013 was $0.4585 per pound, or $3.44 per gallon of biodiesel, compared to $0.3982 per pound, or $2.98 per gallon of biodiesel, for the three months ended March 31, 2014.

Over the period from January 2010 to March 2014, the price of choice white grease, an inedible animal fat (based on daily closing nearby futures prices for The Jacobsen reported Missouri River delivery of choice white grease), have ranged from $0.2325 per pound, or $1.86 per gallon of biodiesel, in February 2010 to $0.5250 per pound, or $4.20 per gallon of biodiesel, in June 2011, assuming 8.0 pounds of choice white grease yields one gallon of biodiesel. The average closing price for choice white grease during 2013 was $0.3767 per pound, or $3.01 per gallon of biodiesel, compared to $0.2922 per pound, or $2.34 per gallon of biodiesel for the three months ended March 31, 2014.

The graph below illustrates the spread between the cost of producing one gallon of biodiesel made from soybean oil to the cost of producing one gallon of biodiesel made from a lower cost feedstock from December 2011 to March 2014. The results were derived using assumed conversion factors for the yield of each feedstock and subtracting the cost of producing one gallon of biodiesel made from each respective lower cost feedstock from the cost of producing one gallon of biodiesel made from soybean oil.


•	Soybean oil (crude) prices are based on the monthly average of the daily closing sale price of the nearby soybean oil contract as reported by CBOT (based on 7.5 pounds per gallons).


(1)	Used cooking oil prices are based on the monthly average of the daily low sales price of Missouri River yellow grease as reported by The Jacobsen (based on 8.5 pounds per gallon).


(2)	Inedible corn oil prices are reported as the monthly average of the daily distillers’ corn oil market values delivered to Illinois as reported by The Jacobsen (based on 8.2 pounds per gallon).


(3)	Choice white grease prices are based on the monthly average of the daily low prices of Missouri River choice white grease as reported by The Jacobsen (based on 8.0 pounds per gallon).

Our results of operations generally will benefit when the spread between biodiesel prices and feedstock prices widens and will be harmed when this spread narrows. The following graph shows feedstock cost data of choice white grease and soybean oil on a per gallon basis compared to the sale price data for biodiesel, and the spread between the two, from December 2011 to March 2014.


(1)	Biodiesel prices are based on the monthly average of the midpoint of the high and low prices of B100 (Upper Midwest) as reported by The Jacobsen.


(2)	Soybean oil (crude) prices are based on the monthly average of the daily closing sale price of the nearby soybean oil contract as reported by CBOT (based on 7.5 pounds per gallon).


(3)	Choice white grease prices are based on the monthly average of the daily low price of Missouri River choice white grease as reported by The Jacobsen (based on 8.0 pounds per gallon).


(4)	Spread between biodiesel price and choice white grease price.


(5)	Spread between biodiesel price and soybean oil (crude) price.

In the first quarter of 2014, feedstock prices generally decreased in January and moved higher in February and March. Notably slower biodiesel production in January due to unseasonably cold temperatures and overhang of 2013 biodiesel inventory put pressure on feedstock prices. A strong rally in palm oil prices helped lead values higher in February and March. Animal fat prices were supported by larger exports and tighter supplies due to a reduction in the number of hogs and cattle going to market.

Risk Management

The profitability of the biodiesel production business largely depends on the spread between prices for feedstocks and biodiesel, including RINs, each of which is subject to fluctuations due to market factors and each of which is not significantly correlated. Adverse price movements for these commodities directly affect our operating results. We attempt to protect operating margins by entering into risk management contracts that mitigate price volatility of our feedstocks, such as inedible corn oil, used cooking oil, inedible animal fat, soybean oil and energy prices. We create offsetting positions by using a combination of forward fixed-price physical purchases and sales contracts on feedstock and biodiesel, including risk management futures contracts, swaps and options primarily on heating oil and soybean oil; however, the extent to which we engage in risk management activities varies substantially from time to time, and from feedstock to feedstock, depending on market conditions and other factors. In making risk management decisions, we utilize research conducted by outside firms to provide additional market information.

Inedible corn oil, used cooking oil, inedible animal fat and soybean oil are the primary feedstocks we used to produce biodiesel in 2013 and the first three months of 2014. We utilize several varieties of inedible animal fat, such as beef tallow, choice white grease and poultry fat derived from livestock. There is no established futures market for these lower cost feedstocks. The purchase prices for lower cost feedstocks are generally set on a negotiated flat price basis or spread to a prevailing market price reported by the USDA price sheet or The Jacobsen. Our limited efforts to risk manage against changing inedible corn oil, used cooking oil and inedible animal fat prices have involved entering into futures contracts, swaps or options on other commodity products, such as soybean oil or heating oil. However, these products do not always experience the same

price movements as lower cost feedstocks, making risk management for these feedstocks challenging. We manage feedstock supply risks related to biodiesel production in a number of ways, including, where available, through long-term supply contracts. For example, most of the feedstock requirements for our Ralston facility were supplied under an agreement with West Central which expires on January 31, 2015 and automatically renews for one additional year unless either party provides sufficient notice of cancellation prior to the renewal. The purchase price for soybean oil under these contracts may be indexed to prevailing CBOT, soybean oil market prices with a negotiated market basis. We utilize futures contracts, swaps and options to risk manage, or lock in, the cost of portions of our future soybean oil requirements generally for varying periods up to one year.

Our ability to mitigate our risk of falling biodiesel prices is limited. We have entered into forward contracts to supply biodiesel. However, pricing under these forward sales contracts generally has been indexed to prevailing market prices, as fixed price contracts for long periods on acceptable terms have generally not been available. There is no established market for biodiesel futures in the United States. Our efforts to hedge against falling biodiesel prices generally involve entering into futures contracts, swaps and options on other commodity products, such as diesel fuel and heating oil. However, price movements on these products are not highly correlated to price movements of biodiesel.

We generate 1.5 biomass-based diesel RINs for each gallon of biodiesel we produce and sell. We also obtain RINs from third party transactions which we hold for resale. There is no established futures market for RINs, which severely limits the ability to risk manage the price of RINs. We enter into forward contracts to sell RINs and we use risk management position limits to manage RIN exposure.

As a result of our strategy, we frequently have gains or losses on derivative financial instruments that are conversely offset by losses or gains on forward fixed-price physical contracts on feedstocks and biodiesel or inventories. Gains and losses on derivative financial instruments are recognized each period in operating results while corresponding gains and losses on physical contracts are generally not recognized until quantities are delivered or title transfers. Our results of operations are impacted when there is a period mismatch of recognized gains or losses associated with the change in fair value of derivative instruments used for risk management purposes at the end of the reporting period when the purchase or sale of feedstocks or biodiesel has not yet occurred and thus the offsetting gain or loss will be recognized in a later accounting period.

We incurred risk management losses of $0.7 million and a gain of $1.4 million from our derivative financial instrument activity for the three months ended March 31, 2014 and 2013, respectively. Changes in the value of these futures or options instruments are recognized in current income or loss. Over the first three months of 2014, we had risk management losses of approximately $0.01 per gallon sold. Over the last three years, risk management losses have represented an expense of approximately $0.02 per gallon sold.

Seasonality

Our operating results are influenced by seasonal fluctuations in the demand for biodiesel. Our sales tend to decrease during the winter season due to blending concentrations being reduced to adjust for performance during colder weather. Colder seasonal temperatures can cause the higher cloud point biodiesel we make from inedible animal fats to become cloudy and eventually gel at a higher temperature than petroleum-based diesel or lower cloud point biodiesel made from soybean oil, canola oil or inedible corn oil. Such gelling can lead to plugged fuel filters and other fuel handling and performance problems for customers and suppliers. Reduced demand in the winter for our higher cloud point biodiesel can result in excess supply of such higher cloud point biodiesel and lower prices for such higher cloud point biodiesel. In addition, most of our production facilities are located in colder Midwestern states in proximity to feedstock origination and our costs of shipping increases as more biodiesel is transported to warmer climate states during winter.

RIN prices may also be subject to seasonal fluctuations. As mentioned above, we generate 1.5 biomass-based diesel RINs for each gallon of biodiesel we produce and sell. The RIN is dated for the calendar year in which it is generated. These RINs are used by Obligated Parties to satisfy their annual RVOs under the RFS2 program. Since only 20% of an Obligated Party's annual RVO can be satisfied by prior year RINs, most RINs must come from biofuel produced or imported during the RVO year. As a result, RIN prices can be expected to decrease as the calendar year progresses if the RIN market is oversupplied compared to that year's RVO and increase if it is undersupplied. In 2011, which had an RVO for biomass-based diesel of 800 million gallons, biomass-based diesel RIN prices, as reported by OPIS, began to decrease in October when biomass-based diesel RIN generation neared the equivalent of 800 million gallons of biomass-based diesel, as reported by EMTS. In 2012, which had an RVO for biomass-based diesel of one billion gallons, biomass-based diesel RIN prices, as reported by OPIS, began to decrease in September when biomass-based diesel RIN generation neared the equivalent of 900 million gallons, as reported by EMTS. For 2013, biomass-based diesel RIN generation was 1.78 billion gallons when the RVO for biomass-based diesel was 1.28 billion gallons. We saw a similar decline in RIN prices in the third and fourth quarter of 2013 as production rates exceeded the RVO target.

Industry capacity and production

Our operating results are influenced by our industry’s capacity and production, including in relation to RFS2 production requirements. According to EMTS data, approximately 1.1 billion gallons of biomass-based diesel was produced in the United States in 2011, primarily reflecting the recommencement of, or increase in, operations at underutilized facilities in response to RFS2 requirements. Such production was in excess of the 800 million gallon RFS2 requirement for 2011. During 2012, according to EMTS data, approximately 1.1 billion gallons of biomass-based diesel was produced, which also was above RFS2 required volumes of 1 billion gallons of biomass-based diesel for 2012. Production in 2011 and 2012 in excess of RFS2 volume requirements put downward pressure on our margins for biodiesel, negatively affecting our profitability in 2012. As reported by EMTS, the biomass-based diesel RIN generation was 1.78 billion gallons in 2013 when the RVO for biomass-based diesel was 1.28 billion. As of this filing, the EPA has proposed the 2014 and 2015 biomass-based diesel RVO at 1.28 billion gallons for each year. Under RFS2, Obligated Parties are entitled to satisfy up to 20% of their annual requirement with prior year RINs, meaning that gallons produced in 2013 could potentially be used to satisfy 256 million gallons of the 1.28 billion gallon requirement for 2014.

Critical Accounting Policies

Our discussion and analysis of our financial condition and results of operations is based upon our financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The preparation of these financial statements requires us to make estimates and judgments that affect the reported amount of assets, liabilities, equities, revenues and expenses and related disclosure of contingent assets and liabilities. We evaluate our estimates on an ongoing basis. We base our estimates on historical experience and on various other assumptions that we believe to be reasonable under the circumstances, the results of which form the basis for judgments we make about the carrying values of assets and liabilities that are not readily apparent from other sources. Because these estimates can vary depending on the situation, actual results may differ from the estimates.

We have disclosed under the heading “Critical Accounting Policies” in our December 31, 2013 Annual Report on Form 10-K the critical accounting policies which materially affect our financial statements. There have been no material changes from the critical accounting policies previously disclosed other than those noted below. You should carefully consider the critical accounting policies set forth in our Annual Report on Form 10-K along with information described below.

Valuation of certain assets and liabilities related to acquisition of LS9. The significant estimates related to our acquisition of LS9 include the valuation of in-process research and development intangible assets, or IPR&D, and contingent consideration. We engaged an independent external valuation specialist to provide assistance in measuring the fair values of these assets and liabilities related to the acquisition.

The fair value of the IPR&D was determined using an income approach called the excess earnings method. Cash flows for specific products for which the IPR&D relate were forecasted, and include estimates for costs to complete research and development activities, projected revenues based upon market data and discussions with market participants and projected operating expenses based on experience with smaller scale production. Appropriate returns for other identifiable assets were then calculated using generally accepted valuation methodologies and deducted from the forecast. These residual cash flows were then discounted to their present value using a risk adjusted discount rate of 25%. This rate reflects the developmental stage of the business and risks associated with development and commercialization of the products. Several scenarios were considered for each IPR&D project to reflect the possible outcomes dependent on future decisions related to production capacity, feedstock inputs and costs and decisions to discontinue development. Each scenario was assigned a probability based on its likelihood of occurring. The estimated fair value of IPR&D was arrived at by adding the probability weighted values of the scenarios considered.

We will pay contingent consideration of $21.5 million to the previous owners of LS9 if, and when, we achieve certain development and commercialization milestones of products from LS9’s technology. Payments for achieving individual product milestones range from $0.5 million to $2.5 million and are payable in either cash or shares of our common stock at our election. The fair value of contingent consideration was determined using an expected probability income approach. We estimated the likelihood of achieving each milestone for each product under development. These probabilities ranged from 0% to 88%. The anticipated time to reaching each milestone was also considered to determine if the payment would be made within the five-year milestone consideration time frame. Both the likelihood of achieving milestones and the related timing were estimated based on the current stage of development and the complexity of completing development and commercialization. If the anticipated time to the milestone fell within the time frame, then the probability-weighted earnout payment was discounted using a risk adjusted discount rate of 8%. The fair value of the contingent consideration will be estimated at the end of each reporting period with changes in fair value running through current period earnings.

Results of Operations

Three months ended March 31, 2014 and 2013

Set forth below is a summary of certain financial information (in thousands) for the periods indicated:



	Three Months Ended March 31,
	2014			2013
Revenues
Biodiesel	$	209,122		$	119,721
Biodiesel government incentives	9,890			144,605
Total biodiesel	219,012			264,326
Services	28			42
Total	219,040			264,368
Costs of goods sold
Biodiesel	207,451			177,613
Services	25			60
Total	207,476			177,673
Gross profit	11,564			86,695
Selling, general and administrative expenses	13,527			9,644
Income (loss) from operations	(1,963		)	77,051
Other income (expense), net	(503		)	(459		)
Income tax benefit (expense)	107			(30,189		)
Net income (loss) attributable to REG	(2,359		)	46,403
Gain on redemption of preferred stock	378			—
Change in undistributed dividends allocated to preferred stockholders	—			(839		)
Distributed dividends to preferred stockholders	(40		)	—
Effects of participating preferred stock	—			(6,510		)
Effects of participating share-based awards	—			(619		)
Net income (loss) attributable to the Company’s common stockholders	$	(2,021	)	$	38,435

Revenues. Our total revenues decreased $45.3 million, or 17%, to $219.0 million for the three months ended March 31, 2014, from $264.4 million for the three months ended March 31, 2013. This decrease was primarily due to reductions in biodiesel government incentives resulting from the expiration of the biodiesel mixture excise tax credit, or BTC, at December 31, 2013.

Biodiesel. Biodiesel revenues including government incentives decreased $45.3 million, or $17%, to $219.0 million for the three months ended March 31, 2014, from $264.3 million for the three months ended March 31, 2013. This decrease in biodiesel revenues is mostly attributable to the net revenue associated with the retroactive reinstatement of the 2012 BTC recorded in the first three months of 2013 of $57.4 million. Gallons sold increased 8.4 million, or 22%, to 47.3 million gallons for the three months ended March 31, 2014, respectively, compared to 38.9 million gallons for the three months ended March 31, 2013. Our average B100 sales price per gallon decreased $0.90, or 20%, to $3.54 for the three months ended March 31, 2014 compared to $4.44 for the three months ended March 31, 2013, respectively. The decrease in average sales price for the three months ended March 31, 2014 contributed to a $35.0 million revenue decrease when applied to the number of gallons sold during the respective period of 2013. The increase in gallons sold for the three months ended March 31, 2014 accounted for revenue increases of $29.7 million for the three months ended March 31, 2014 using pricing for the respective period of 2014. Sales of separated RIN inventory were $30.0 million and $15.1 million for the three months ended March 2014 and 2013, respectively. The decrease in government incentives relates to the expiration of the BTC at December 31, 2013.

Services. Service revenues were minimal for the three months ended March 31, 2014 and 2013, respectively.

Costs of goods sold. Our costs of goods sold increased $29.8 million, or 17%, to $207.5 million for the three months ended March 31, 2014 from $177.7 million for the three months ended March 31, 2013. Costs of goods sold as a percentage of revenues were 95% and 67% for the three ended March 31, 2014 and 2013, respectively. The increase in costs of goods sold as a percentage of revenues during the three months ended March 31, 2014, was primarily due to the recognition of 2012 BTC net

revenue recognized in January 2013. In addition, the unseasonably cold weather reduced overall diesel demand, as well as biodiesel blends, and our production facilities saw an increase in utility expense, primarily due to increase in natural gas prices.

Biodiesel. Biodiesel costs of goods sold increased $29.8 million, or 17%, to $207.5 million for the three months ended March 31, 2014, compared to $177.6 million for the three months ended March 31, 2013. The costs of goods sold increased due to additional gallons sold in the first three months 2014 and was partially offset by slightly lower feedstock prices in 2014 as compared to 2013. Average lower cost feedstocks prices were $0.32 and $0.39 for the three months ended March 31, 2014 and 2013, respectively. Soybean oil costs were $0.40 and $0.52 for the three months ended March 31, 2014 and 2013, respectively. We had losses of $0.7 million and gains of $1.4 million from risk management trading activity for the three months ended March 31, 2014 and 2013, respectively. Costs of goods sold for separated RIN inventory sales were $17.8 million and $12.7 million for the three months ended March 31, 2014 and 2013, respectively. Biodiesel costs of goods sold as a percentage of revenues were 95% and 67% for the three months ended March 31, 2014 and 2013, respectively. This increase was primarily due to BTC net revenues in 2013 and lower biodiesel prices during 2014 compared to 2013 as noted above.

Services. Services expenses were minimal for the three months ended March 31, 2014 and 2013, respectively.

Selling, general and administrative expenses. Our selling, general and administrative, or SG&A, expenses were $13.5 million and $9.6 million for the three months ended March 31, 2014 and 2013, respectively. This increase of $3.9 million, or 41%, was primarily due to an increase in research and development costs of $1.9 million related to our acquisition of LS9, a $0.6 million increases in wages and benefits and a $0.4 million increase in legal and professional expenses.

Other income (expense), net. Other expense was $0.5 million for both the three months ended March 31, 2014 and 2013, respectively. Other income (expense) is primarily comprised of interest expense, interest income and the other non-operating items.

Income tax benefit (expense). We recognized an income tax benefit of $0.1 million and an income tax expense of $30.2 million for the three months ended March 31, 2014 and 2013, respectively. We generated significant net operating loss carryforward for tax purposes and established a valuation reserve for a significant portion of our deferred tax assets in the third quarter of 2013 when we recognized the impact of excluding certain governmental incentives from taxable income. The tax benefit or expense in subsequent periods, including the three months ended 2014, has not been significant as most of the current tax benefit or expense has been offset by similar changes in the valuation allowance.

Gain on redemption of preferred stock. We recognized a gain of $0.4 million which represents the difference between the carrying amount and the amount we paid to redeem all of the then outstanding Series B Preferred Stock shares in March 2014.

Change in undistributed dividends. As a result of the above mentioned redemption of the Series B preferred stock, there were no undistributed preferred stock dividends for the three months ended March 31, 2014.

Distributed dividends. Distributed dividends related to the Series B Preferred Stock upon redemption were minimal for the three months ended March 31, 2014. There were no distributed dividends for the three months ended March 31, 2013.

Effects of participating preferred stock. Effects of participating preferred stock was a gain of $0.1 million and a loss of $6.5 million for the three months ended March 31, 2014 and 2013, respectively.

Effects of participating share-based awards. Effects of participating restricted stock units were minimal for the three months ended March 31, 2014 and 2013, respectively.

Liquidity and Capital Resources

Sources of liquidity. At March 31, 2014, the total of our cash and cash equivalents and our marketable securities was $136.1 million compared to $153.2 million at December 31, 2013. At March 31, 2014, we had total assets of $755.4 million compared to $740.9 million at December 31, 2013. At March 31, 2014, we had term debt of $33.2 million, compared to term debt of $34.2 million at December 31, 2013. There were outstanding borrowings on our revolving line of credit of $2.4 million and $11.0 million at March 31, 2014 and December 31, 2013, respectively.

Our borrowings (in millions) are as follows:



	March 31, 2014		December 31, 2013
REG Danville term loan	$	5.3	$	5.6
REG Newton term loan	17.5		18.1
REG Mason City term loan	5.1		5.1
Other	1.3		1.4
Total notes payable	$	29.2	$	30.2
Bell, LLC promissory note	$	4.0	$	4.0

We have disclosed under the heading “Liquidity and Capital Resources” in our December 31, 2013 Annual Report on Form 10-K the capital resources which materially affect our financial statements. There have been no material changes from the capital resources previous disclosed other than those noted below. You should carefully consider the liquidity and capital resources set forth in our Annual Report on Form 10-K along with the information described below.

We and our subsidiaries were in compliance with all restrictive financial covenants associated with our borrowings as of March 31, 2014.

Cash flow. The following table presents information regarding our cash flows and cash and cash equivalents for the three months ended March 31, 2014 and 2013 (in thousands):



	Three Months Ended March 31,
	2014			2013
Net cash flows provided by (used in) operating activities	$	24,820		$	(34,127	)
Net cash flows used in investing activities	(87,911		)	(9,981		)
Net cash flows provided by (used in) financing activities	(13,912		)	26,300
Net change in cash and cash equivalents	(77,003		)	(17,808		)
Cash and cash equivalents, end of period	$	76,224		$	48,977

Operating activities. Net cash provided by operating activities was $24.8 million for the three months ended March 31, 2014. For the first three months of 2014, net loss was $2.4 million, which includes depreciation and amortization expense of $3.0 million, stock-based compensation expense of $1.2 million and an expense for deferred tax benefit of $0.3 million. We also had a change of $23.6 million in net working capital, consisting of an $8.3 million increase in inventory, a $52.2 million decrease in accounts receivable and a $3.7 million increase in prepaid expenses, which was offset by a $13.0 million decrease in accounts payable and accruals and a decrease in deferred revenues of $3.7 million.

Net cash used in operating activities was $34.1 million for the three months ended March 31, 2013. For the first quarter of 2013, net income was $46.4 million, which includes depreciation and amortization expense of $1.9 million, stock compensation expense of $1.4 million and an expense for deferred taxes of $2.5 million. We also used $86.1 million to fund net working capital requirements, consisting of a $44.3 million increase in inventory, $153.4 million increase in accounts receivable, of which $127.9 of the accounts receivable increase relates to the retroactive 2012 BTC passed into law on January 2, 2013, and a $2.9 million increase in prepaid expenses, which was offset by a $113.1 million increase in accounts payable and accruals and an increase in deferred revenues of $1.4 million.

Investing activities. Net cash used in investing activities for the three months ended March 31, 2014 was $87.9 million, consisting primarily of marketable securities purchases of $59.9 million, $15.3 million to purchase the LS9 business and $12.8 million to pay for upgrades to the Albert Lea, New Boston, Mason City and Seneca facilities.

Net cash used in investing activities for the three months ended March 31, 2013 was $10.0 million, consisting mainly of net cash used to pay for facility construction of $9.9 million for upgrades at REG Albert Lea, REG New Boston and REG Seneca.

Financing activities. Net cash used in financing activities for the three months ended March 31, 2014 was $13.9 million. We paid down a net amount of $8.5 million on our line of credit and $1.0 million of notes payable. We paid $3.6 million for redemption of preferred stock. We also paid $0.5 million for the purchase of treasury stock.

Net cash provided from financing activities for the three months ended March 31, 2013 was $26.3 million. We paid $0.3 million for the purchase of treasury stock. We drew down a net amount of $27.4 million on our line of credit and paid down $0.8 million of term debt.

Capital expenditures. We have three partially constructed plants, one near New Orleans, Louisiana, one in Emporia, Kansas, one in Clovis, New Mexico and a non-operational plant near Atlanta, Georgia. We expect additional investments of approximately $145 to $160 million in the aggregate, excluding working capital requirements, may be invested before these plants would be able to commence production. These facilities would add an expected 150 mmgy to our nameplate production capacity. Our Clovis plant is currently being operated as a terminal facility. We plan to make significant capital expenditures when debt or equity financing becomes available to complete construction of these four facilities. In 2013, we completed upgrades to our Albert Lea facility, our New Boston facility, our Mason City facility and our Seneca facility. Capital expenditures related to these facility upgrades were approximately $22 million, $4 million and $1 million and $5 million, respectively, in 2013. We also plan to undertake an additional $20 million upgrade at our Mason City facility along with various facility upgrades at our existing facilities to further expand processing capabilities. We may enter into additional tolling arrangements with third parties from time to time where third parties will produce biodiesel on our behalf using our feedstocks. Such arrangements may require investments of additional working capital during the tolling periods.

We continue to be in discussions with lenders in an effort to enter into equity and debt financing arrangements to meet our projected financial needs for facilities under construction and capital improvement projects for our operating facilities. Since these discussions are ongoing, we are uncertain when or if financing will be available. The financing may consist of common or preferred stock, debt, project financing or a combination of these financing techniques. Additional debt would likely increase our leverage and interest costs and would likely be secured by certain of our assets. Additional equity or equity-linked financings would likely have a dilutive effect on our existing and future stockholders. It is likely that the terms of any project financing would include customary financial and other covenants on our project subsidiaries, including restrictions on the ability to make distributions, to guarantee indebtedness and to incur liens on the plants of such subsidiaries.

Adjusted EBITDA

We use earnings before interest, taxes, depreciation and amortization, adjusted for certain additional items, identified in the table below, or Adjusted EBITDA, as a supplemental performance measure. We present Adjusted EBITDA because we believe it assists investors in analyzing our performance across reporting periods on a consistent basis by excluding items that we do not believe are indicative of our core operating performance. In addition, we use Adjusted EBITDA to evaluate, assess and benchmark our financial performance on a consistent and a comparable basis and as a factor in determining incentive compensation for our executives.

The following table provides our Adjusted EBITDA for the periods presented, as well as a reconciliation to net income:



(In thousands)	Three Months Ended March 31, 2014			Three Months Ended March 31, 2013
Net income (loss)	$	(2,359	)	$	46,403
Adjustments:
Income tax (benefit) expense	(107		)	30,189
Interest expense	551			576
Other (income) expense, net	(48		)	(117		)
Straight-line lease expense	(163		)	(159		)
Depreciation	3,004			2,080
Amortization	(185		)	(199		)
Non-recurring business interruption (1)	—			(863		)
Biodiesel mixture excise tax credit (2)	—			(57,372		)
Stock-based compensation	1,235			1,356
Adjusted EBITDA	$	1,928		$	21,894


(1)	We incurred a non-recurring business interruption charge at one of our production facilities in November 2012; we reflected the gain contingency in our operating performance of 2012 having received the corresponding insurance proceeds in February 2013, thus excluding it from first quarter 2013 adjusted EBITDA.


(2)	On January 2, 2013, the American Taxpayer Relief Act of 2012 was signed into law, which reinstated a set of tax extender items including the reinstatement of the BTC for 2013 and retroactively reinstated the credit for 2012. The retroactive credit for 2012 resulted in a net benefit to us that was recognized in first quarter 2013, but because this credit relates to the

operating performance and results of 2012 it is excluded from 2013 adjusted EBITDA and allocated to the 2012 periods based upon gallons sold.

Adjusted EBITDA is a supplemental performance measure that is not required by, or presented in accordance with, generally accepted accounting principles, or GAAP. Adjusted EBITDA should not be considered as an alternative to net income or any other performance measure derived in accordance with GAAP, or as alternatives to cash flows from operating activities or a measure of our liquidity or profitability. Adjusted EBITDA has limitations as an analytical tool, and should not be considered in isolation, or as a substitute for any of our results as reported under GAAP. Some of these limitations are:


•	Adjusted EBITDA does not reflect our cash expenditures for capital assets or the impact of certain cash clauses that we consider not to be an indication of our ongoing operations;


•	Adjusted EBITDA does not reflect changes in, or cash requirements for, our working capital requirements;


•	Adjusted EBITDA does not reflect the interest expense, or the cash requirements necessary to service interest or principal payments, on our indebtedness;


•	although depreciation and amortization are non-cash charges, the assets being depreciated and amortized will often have to be replaced in the future, and Adjusted EBITDA does not reflect cash requirements for such replacements;


•	stock-based compensation expense is an important element of our long term incentive compensation program, although we have excluded it as an expense when evaluating our operating performance; and


•	other companies, including other companies in the industry, may calculate these measures differently than we do, limiting their usefulness as a comparative measure.

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements.

Recent Accounting Pronouncements

For a discussion of new accounting pronouncements affecting the Company, refer to “Note 2 – Summary of Significant Accounting Policies” to our condensed consolidated financial statements.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

The primary objectives of our investment activity are to preserve principal, provide liquidity and maximize income without significantly increasing risk. Some of the securities we invest in are subject to market risk. This means that a change in prevailing interest rates may cause the principal amount of the investment to fluctuate. To minimize this risk, we maintain a portfolio of cash equivalents in short-term investments in money market funds.

Commodity Price Risk

Over the period from January 2010 through March 2014, average diesel prices based on Platts reported pricing for Group 3 (Midwest) have ranged from a high of approximately $3.64 per gallon reported in October 2012 to a low of approximately $1.82 per gallon in February 2010, with prices averaging $2.83 per gallon during this period. Over the period from January 2010 through March 2014, soybean oil prices (based on closing sales prices on the CBOT nearby futures, for crude soybean oil) have ranged from a high of $0.5977 per pound in April 2011 to a low of $0.3584 per pound in July 2010, with closing sales prices averaging $0.3982 per pound during this period. Over the period from January 2010 through March 2014, animal fat prices (based on prices from The Jacobsen Missouri River, for choice white grease) have ranged from a high of $0.5250 per pound in June 2011 to a low of $0.2325 per pound in February 2010, with sales prices averaging $0.2922 per pound during this period. Over the period from July 2010 through March 2014, RIN prices (based on prices from OPIS) have ranged from a high of $1.99 in September 2011 to a low of $0.21 in November 2013, with sales prices averaging $0.5645 during this period.

Higher feedstock prices or lower biodiesel prices result in lower profit margins and, therefore, represent unfavorable market conditions. Traditionally, we have not been able to pass along increased feedstock prices to our biodiesel customers. The availability and price of feedstocks are subject to wide fluctuations due to unpredictable factors such as weather conditions during the growing season, rendering volumes, carry-over from the previous crop year and current crop year yield, governmental policies with respect to agriculture and supply and demand.

We have prepared a sensitivity analysis to estimate our exposure to market risk with respect to our sales contracts, lower cost feedstock requirements, soybean oil requirements and the related exchange-traded contracts for 2013. Market risk is estimated as the potential loss in fair value, resulting from a hypothetical 10% adverse change in the fair value of our lower cost feedstock and soybean oil requirements and biodiesel sales. The results of this analysis, which may differ from actual results, are as follows:



	2013 Volume (in millions)	Units	Hypothetical Adverse Change in Price		Annual Gross Profit (in millions)		Percentage Change in Gross Profit
Biodiesel	258.6	gallons	10	%	$	120.8	50.1	%
Lower Cost Feedstocks	1,564.1	pounds	10	%	$	60.8	25.2	%
Soybean Oil	327.4	pounds	10	%	$	15.7	6.5	%

We attempt to protect operating margins by entering into risk management contracts that mitigate price volatility of our feedstocks, such as inedible animal fat and inedible corn oil and energy prices. We create offsetting positions by using a combination of forward physical purchases and sales contracts on feedstock and biodiesel, including risk management futures contracts, swaps and options primarily on heating oil and soybean oil; however, the extent to which we engage in risk management activities varies substantially from time to time, and from feedstock to feedstock, depending on market conditions and other factors. A 10% adverse change in the prices of heating oil would have a negative effect on the fair value of these instruments of $8.1 million. A 10% adverse change in the price of soybean oil would have a negative effect on the fair value of these instruments of $0.5 million.

Interest Rate Risk

We are subject to interest rate risk in connection with our $1.0 million loan from the proceeds of Variable Rate Demand Industrial Development Revenue Bonds, or IFA Bonds, issued by the Iowa Finance Authority to finance our Ralston facility. The IFA Bonds bear interest at a variable rate determined by the remarketing agent from time to time as the rate necessary to produce a bid for the purchase of all of the Bonds at a price equal to the principal amount thereof plus any accrued interest at the time of determination, but not in excess of 10% per annum. The interest rate on the bonds was 0.10% for the last week of March 31, 2014. A hypothetical increase in interest rate of 10% would not have a material effect on our annual interest expense.

We are subject to interest rate risk relating to REG Danville’s $5.3 million term debt financing which matures in November 2014. The term loan bears interest at a fluctuating rate based on LIBOR. Interest will accrue on the outstanding balance of the term loan at LIBOR plus 500 basis points. Interest accrued on the outstanding balance of the loan at March 31 at 5.15%. A hypothetical increase in interest rate of 10% would not have a material effect on our annual interest expense.

REG Newton is subject to interest rate risk relating to its $17.5 million term debt financing from AgStar. Interest will accrue on the outstanding balance of the term loan at 30-day LIBOR plus 400 basis points (effective rate at March 31, 2014 of 4.16%). A hypothetical increase in interest rate of 10% would not have a material effect on our annual interest expense.

We are subject to interest rate risk under our Wells Fargo Revolver which matures in December 2016 under which we had $2.4 million borrowed and outstanding at March 31, 2014. The loans bear interest at (a) LIBOR plus a margin ranging from 2.50% to 3.25% or (b) the greatest of (i) 1.75% per annum, (ii) the Federal Funds Rate plus 0.5%, (iii) the LIBOR Rate plus 1.5%, or (iv) the “prime rate” plus 1.00% to 1.75%. The effective interest rate was 3.75% at March 31, 2014. The loan was a base rate loan as of March 31, 2014 (effective rate at March 31, 2014 of 3.75%). A hypothetical increase in interest rate of 10% would not have a material effect on our annual interest expense.

Investment Exposure

We are exposed to investment risk as it relates to changes in the market value of our investments. Our cash and marketable securities investment policy and strategy attempts primarily to preserve capital and meet liquidity requirements. A large portion of our cash is managed by external managers within the guidelines of our investment policy. We protect and preserve invested funds by limiting default, market, and reinvestment risk. To achieve this objective, we maintain our portfolio of cash and cash equivalents and short-term and long-term investments in a variety of liquid fixed income securities, including both government and corporate obligations and money market funds. As of March 31, 2014 and December 31, 2013, net unrealized gains and losses on these investments were not material.

Inflation

To date, inflation has not significantly affected our operating results, though costs for petroleum-based diesel fuel, feedstocks, construction, labor, taxes, repairs, maintenance and insurance are all subject to inflationary pressures. Inflationary pressure in the future could affect our ability to sell the biodiesel we produce, maintain our production facilities adequately, build new biodiesel production facilities and expand our existing facilities as well as the demand for our facility construction management and operations management services.

ITEM 4. CONTROLS AND PROCEDURES

We maintain a system of disclosure controls and procedures that are designed to ensure that information required to be disclosed in the Company’s reports under the Securities Exchange Act of 1934, as amended (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, including our Chief Executive Officer and the Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure. In designing and evaluating the disclosure controls and procedures, management recognized that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives.

Management, with the participation of our Chief Executive Officer and our Chief Financial Officer, has evaluated the effectiveness of our disclosure controls and procedures, as defined in Rule 13a-15(e) of the Exchange Act, as of March 31, 2014. Based on that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of March 31, 2014.

There were no changes in our internal control over financial reporting (as defined in Rules 13a-15(f) under the Exchange Act) that occurred during the three months ended March 31, 2014 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

We may from time to time be involved in claims, proceedings and litigation arising from our business and property ownership. We believe, based on currently available information, that the results of such proceedings, in the aggregate, will not have a material adverse effect on our financial position, operations or liquidity.

ITEM 1A. RISK FACTORS

Our business, financial condition, results of operations and liquidity are subject to various risks and uncertainties, including those described below, and as a result, the trading price of our common stock could decline.

Risk Associated With Our Business

Loss or reductions of governmental requirements for the use of biofuels could have a material adverse effect on our revenues and operating margins.

The biodiesel industry relies substantially on federal requirements and state policies for use of biofuels. Since biodiesel has been more expensive to produce than petroleum-based diesel fuel over the past few years, the biodiesel industry depends on governmental programs that support a market for biodiesel that might not otherwise exist.

The most important of these government programs in the United States is RFS2, which requires that a certain volume of biomass-based diesel fuel, which includes biodiesel, be consumed. RFS2 became effective on July 1, 2010 and applies through 2022. We believe that the increase in demand for our biodiesel since July 2010 is directly attributable to the implementation of RFS2. In addition, we believe that biodiesel prices since July 2010 benefited significantly from RFS2.

There can be no assurance that the United States Congress will not repeal, curtail or otherwise change, or that the EPA will not curtail or otherwise change the RFS2 program in a manner adverse to us. The petroleum industry is generally opposed to RFS2 and can be expected to continue to press for changes that eliminate or reduce its impact. Any repeal or reduction in the RFS2 requirements or reinterpretation of RFS2 resulting in our biodiesel failing to qualify as a required fuel would materially decrease the demand for and price of our biodiesel, which would materially and adversely harm our revenues and cash flows.

If Congress decides to repeal or curtail RFS2, or if the EPA is not able or willing to enforce RFS2 requirements, the demand for our biodiesel based on this program and any increases in demand that we expect due to RFS2 would be significantly reduced or eliminated and our revenues and operating margins would be materially harmed. In addition, although we believe that state requirements for the use of biofuels increase demand for our biodiesel within such states, they generally may not increase overall demand in excess of RFS2 requirements. Rather, existing demand for our biofuel from petroleum refiners and petroleum fuel importers in the 48 contiguous states or Hawaii, which are defined as “Obligated Parties” in the RFS2 regulations, in connection with federal requirements, may shift to states that have use requirements or tax incentive programs.

The EPA is required to determine the volume of biomass-based diesel that will be required each year beginning in 2013 based on the EPA’s consideration of a variety of factors, including biomass-based diesel production, consumption, and infrastructure issues, the likely impact of biomass-based diesel production and use in a variety of areas, including climate change, energy security, the agricultural sector, air quality, transportation fuel costs, job creation, and water quality, and other

factors. RFS2 requires that the biomass-based diesel annual volume requirement be at least 1 billion gallons in each of those years. The biomass-based diesel volume requirement for 2013 was 1.28 billion gallons.

According to EMTS data, 0.33 billion gallons of biomass-based diesel was produced for the three months ended March 31, 2014. As of the date of this filing, the EPA has not finalized the 2014 Renewable Volume Obligations, or RVOs. The EPA has proposed a 2014 and 2015 biomass-based diesel RVO of 1.28 billion gallons in each of those years and a reduced Advanced Biofuel RVO of 2.0 to 2.51 billion gallons rather than the original Energy Independence and Security Act of 2009, or EISA, volume of 3.75 billion gallons for 2014. Before the RVO can be finalized, the OMB, has to approve EPA’s proposal, based on the same factors outlined above. Due to the one year delay publishing the proposal, which the EPA was required to determine and publish by November 30, 2012, it is possible that the 2014 RVOs will be challenged in court which may further delay any final determination of the 2014 RVOs, which could reduce the demand for and price of our biodiesel and could harm its revenues and cash flows.

As an illustrative example, according to EMTS data, 1.78 billion gallons of biomass-based diesel was produced and imported into the U.S. in 2013. Adding the 2012 carry-over to the 2013 RIN generation results in an estimated total biomass-based diesel RIN availability of approximately 2.04 billion gallons, which is approximately 760 million gallons more than required to satisfy the 1.28 billion gallon 2013 biomass-based diesel RVO. The proposed 2014 biomass-based diesel RVO of 1.28 billion gallons, would limit the 2014 carryover to 256 million gallons, or 20% of 1.28 billion, thus resulting in an excess supply of 504 million gallons of biomass-based diesel RINs. These excess RINs may be used to fulfill the advanced biofuel RVO or the renewable fuel RVO. If the volume of excess biomass-based diesel RINs exceeds the volume the Obligated Parties desire to use to fulfill their advanced biofuel and renewable fuel requirements, the demand for and price of our biodiesel and biomass-based diesel RINs may be reduced, which could harm revenues and cash flows.

Our gross margins are dependent on the spread between biodiesel prices and feedstock costs.

Our gross margins depend on the spread between biodiesel prices and feedstock costs. Historically, the spread between biodiesel prices and feedstock costs has varied significantly. Although actual yields vary depending on the feedstock quality, the average monthly spread between the price per gallon of 100% pure biodiesel, or B100, as reported by The Jacobsen Publishing Company, or The Jacobsen, and the price per gallon for the amount of choice white grease, a common inedible animal fat used by us to make biodiesel, was $1.32 in 2011, $1.26 in 2012, and $1.61 in 2013 assuming 8.0 pounds of choice white grease yields one gallon of biodiesel. The average monthly spread for the amount of crude soybean oil required to produce one gallon of biodiesel, based on the nearby futures contract as reported on the Chicago Board of Trade, or CBOT, was $0.89 in 2011, $0.65 in 2012, and $1.19 in 2013 assuming 7.5 pounds of soybean oil yields one gallon of biodiesel. For 2011, 2012 and 2013, approximately 83%, 84%, and 83%, respectively, of our total feedstock usage was inedible animal fat, used cooking oil or inedible corn oil and 17%, 16% and 17%, respectively, was virgin vegetable oils.

Biodiesel has traditionally been marketed primarily as an additive or alternative to petroleum-based diesel fuel and as a result biodiesel prices have been influenced by the price of petroleum-based diesel fuel, adjusted for government incentives supporting renewable fuels, rather than biodiesel production costs. A lack of close correlation between production costs and biodiesel prices means that we may be unable to pass increased production costs on to our customers in the form of higher prices. Any decrease in the spread between biodiesel prices and feedstock costs, whether as a result of an increase in feedstock prices or a reduction in biodiesel prices, including, but not limited to, a reduction in the value of RINs, such as the decrease that occurred in the last few months of 2012 and the last few months of 2013, would adversely affect our gross margins, cash flow and results of operations. For a detailed description of RINs, see “Business-Government Programs Favoring Biodiesel Production and Use-Renewable Identification Numbers.”

The costs of raw materials that we use as feedstocks are volatile and our results of operations could fluctuate substantially as a result.

The cost of feedstocks is a significant uncertainty for our business. The success of our operations is dependent on the price of feedstocks and certain other raw materials that we use to produce biodiesel. A decrease in the availability or an increase in the price of feedstocks may have a material adverse effect on our financial condition and operating results. At elevated price levels, these feedstocks may be uneconomical to use, as we may be unable to pass feedstock cost increases on to our customers.

The price and availability of feedstocks and other raw materials may be influenced by general economic, market and regulatory factors. These factors include weather conditions, farming decisions, government policies and subsidies with respect to agriculture and international trade and global supply and demand. The significance and relative impact of these factors on the price of feedstocks is difficult to predict, especially without knowing what types of feedstock materials will be optimal for use in the future, particularly at new facilities that we may construct or acquire.

Since 2009, we have principally used inedible corn oil, used cooking oil and inedible animal fats as our feedstocks for the production of biodiesel. Our decision to shift to these feedstocks resulted from the reduction in profit caused by a significant increase in soybean oil prices, which rose from $0.1435 per pound in February 2001 to $0.7040 per pound in March 2008, and

soybean oil having generally remained at high levels since that time. While prices for these alternative feedstocks can experience price volatility similar to soybean oil, their prices can also vary significantly from soybean oil based on market conditions. Since January 1, 2008, the cost per pound of choice white grease, an inedible animal fat commonly used by us in the production of biodiesel, has traded in a range of $0.0950 to $0.5250 based on the closing nearby futures prices on the CBOT. Historically, the price of animal fat has been affected by the amount of rendering volumes in the United States, as well as demand from other markets. If biodiesel production continues to increase in response to RFS2, we expect that more biodiesel producers will seek to use lower cost feedstocks, potentially increasing our costs of production. In addition, because the market for animal fat is less developed than markets for vegetable oils such as soybean oil, we generally are unable to enter into forward contracts at fixed prices. Further, the markets for used cooking oil and inedible corn oil are in their nascent stages.

The market and supply for used cooking oil as a feedstock for biodiesel is growing. The commercial supply of inedible corn oil is growing as more ethanol producers are installing corn oil extraction technology in their ethanol plants and are improving the yield of inedible corn oil they are able to extract from their distillers grains. However, inedible corn oil is not generally available in quantities sufficient to cover all of our operations. If more ethanol plants do not acquire and utilize corn oil extraction equipment, if extraction yields do not improve, or if ethanol plants are idled, we may not be able to obtain additional amounts of inedible corn oil for use in our production of biodiesel and may be forced to utilize higher cost feedstocks to meet increased demand, which may not be economical.

Loss of or reductions in tax incentives for biodiesel production or consumption may have a material adverse effect on industry revenues and operating margins.

The biodiesel industry has historically been substantially aided by federal and state tax incentives. Prior to RFS2, the biodiesel industry relied principally on these tax incentives to bring the price of biodiesel more in line with the price of petroleum-based diesel fuel to the end user. The most significant tax incentive program has been the federal biomass-based diesel mixture excise tax credit, or BTC. The BTC provided a $1.00 refundable tax credit per gallon of pure biodiesel, or B100, to the first blender of biodiesel with petroleum-based diesel fuel. The BTC came into existence on January 1, 2005, had been continuously reinstated until it expired on December 31, 2009 and was re-enacted in December 2010, retroactively for all of 2010 and prospectively for 2011. The BTC expired again on December 31, 2011 and was again reinstated on January 2, 2013, retroactively for all of 2012 and prospectively for 2013, and expired again December 31, 2013. There is no assurance that it will be reinstated again. Unlike RFS2, the BTC has a direct effect on federal government spending and could be changed or eliminated as a result of changes in the federal budget policy. Although the BTC was reinstated for all of 2012, it was restated in January of 2013 and thus is reflected in our 2013 earnings. It is uncertain what action, if any, Congress may take with respect to reinstating the BTC or when such action might be effective. If Congress does not reinstate the credit, demand for our biodiesel and the price we are able to charge for our product may be significantly reduced, harming revenues and profitability. When the BTC expired on December 31, 2011, we experienced an industry-wide acceleration of gallons sold in the fourth quarter of 2011, which was further influenced by the ability of Obligated Parties to satisfy up to 20% of their current RVO with prior year RINs. We believe this increase in production at the end of the year resulted in a buildup of biodiesel inventories and reduced gallons sold in the first quarter of 2012. With the expiration of the BTC at the end of 2013, the industry experienced a similar surge in biodiesel production in the fourth quarter of 2013 which impacted demand in the first quarter of 2014 as a result.

In addition, several states have enacted tax incentives for the use of biodiesel. For example, Illinois offers an exemption from the generally applicable 6.25% sales tax for biodiesel blends that incentivizes blending at 11% biodiesel, or B11. Like the BTC, the Illinois tax incentive program and the tax incentive programs of other state could be changed as a result of state budget considerations or otherwise. Reduction or elimination of such incentives could materially and adversely harm our revenues and profitability.

Risk management transactions could significantly increase our operating costs and working capital requirements and may not be effective.

In an attempt to partially offset the effects of volatile feedstock costs and biodiesel fuel prices, we may enter into contracts that establish market positions in feedstocks, such as inedible corn oil, used cooking oil, inedible animal fats and soybean oil, and related commodities, such as heating oil and ultra-low sulfur diesel, or ULSD. The financial impact of such market positions will depend on commodity prices at the time that we are required to perform our obligations under these contracts. Risk management arrangements will also expose us to the risk of financial loss in situations where the counterparty defaults on its contract or, in the case of exchange-traded or over-the-counter futures or options contracts, where there is a change in the expected differential between the underlying price in the contract and the actual prices paid or received by us. Risk management activities can themselves result in losses when a position is purchased in a declining market or a position is sold in a rising market. Changes in the value of these futures instruments are recognized in current income and may result in margin calls. We may also vary the amount of risk management strategies we undertake, or we may choose not to engage in risk management transactions at all. Further, our ability to reduce the risk of falling biodiesel prices and rising feedstock costs will be limited as currently there is no established futures market for biodiesel or the vast majority of our feedstocks, nor are

fixed-price long-term contracts generally available. As a result, our results of operations and financial position may be adversely affected by increases in the price of feedstocks or decreases in the price of biodiesel that are not managed effectively.

One customer accounted for a meaningful percentage of revenues and a loss of this customer could have an adverse impact on our total revenues.

One customer, Pilot Travel Centers LLC, or Pilot, accounted for 16%, 36% and 23% of our total revenues in 2013, 2012 and 2011, respectively. Our agreements with Pilot have typically had a one-year term and our current agreement with Pilot expires December 31, 2014. In the event we lose Pilot as a customer or Pilot significantly reduces the volume of biodiesel it buys from us, it could be difficult to replace the lost revenues in the short term and potentially over an extended period, and our profitability and cash flow could be materially harmed. Past news reports indicated that Pilot was the subject of a federal criminal investigation involving alleged fraud related to customer diesel fuel rebates. REG cannot determine what effect, if any, this may have on its future business relationship with Pilot.

Our business is primarily dependent upon one product. As a consequence, we may not be able to adapt to changing market conditions or endure any decline in the biodiesel industry.

Our revenues are currently generated almost entirely from the production and sale of biodiesel, with glycerin and fatty acid sales and the operations of our Services segment representing only a small portion of revenues. To date, our renewable chemicals business has not generated any revenues. Our reliance on biodiesel means that we may not be able to adapt to changing market conditions or to withstand any significant decline in the size or profitability of the biodiesel industry. For example, in 2009 and the beginning of 2010, we were required to periodically idle our plants due to insufficient demand at profitable price points which materially affected our revenues. If we are required to idle our plants in the future or are unable to adapt to changing market conditions, our revenues and results of operations may be materially harmed.

Technological advances and changes in production methods in the biodiesel industry could render our plants obsolete and adversely affect our ability to compete.

It is expected that technological advances in biodiesel production methods will continue to occur and new technologies for biodiesel production may develop. Advances in the process of converting oils and fats into biodiesel could allow our competitors to produce biodiesel faster and more efficiently and at a substantially lower cost. If we are unable to adapt or incorporate technological advances into our operations, our production facilities could become less competitive or obsolete. Further, it may be necessary for us to make significant expenditures to acquire any new technology and retrofit our plants in order to incorporate new technologies and remain competitive. There is no assurance that third-party licenses for any proprietary technologies that we would need access to in order to remain competitive for either existing processes or new technology will be available to us on commercially reasonable terms or that any new technologies could be incorporated into our plants. In order to execute our strategy to expand into the production of renewable chemicals, additional advanced biofuels, next generation feedstocks and related renewable products, we may need to acquire licenses or other rights to technology from third parties. We can provide no assurance that we will be able to obtain such licenses or rights on favorable terms. If we are unable to obtain, implement or finance new technologies, our production facilities could be less efficient than our competitors, we may not be able to successfully execute our strategy and our results of operations could be substantially harmed.

If we are unable to respond to changes in ASTM or customer standards, our ability to sell biodiesel may be harmed.

We currently produce biodiesel to conform to or exceed standards established by ASTM. ASTM standards for biodiesel and biodiesel blends may be modified in response to new observations from the industries involved with diesel fuel. New tests or more stringent standards may require us to make additional capital investments in, or modify, plant operations to meet these standards. In addition, some biodiesel customers have developed their own biodiesel standards which are stricter than the ASTM standards. If we are unable to meet new ASTM standards or our biodiesel customers’ standards cost effectively or at all, our production technology may become obsolete, and our ability to sell biodiesel may be harmed, negatively impacting our revenues and profitability.

Increases in our transportation costs or disruptions in our transportation services could have a material adverse effect on our business.

Our business depends on transportation services to deliver our products to our customers and to deliver raw materials to us. The costs of these transportation services are affected by the volatility in fuel prices, such as those caused by recent geopolitical and economic events. For example, in 2012, the market rates of leasing new rail cars nearly doubled as a result of increased demand to move domestically drilled crude oil from new supply fields in the upper Midwest to various refineries. We have not been able in the past, and may not be able in the future, to pass along part or all of any of these increases to customers. If we continue to be unable to increase our prices as a result of increased fuel costs charged to us by transportation providers, our gross margins may be materially adversely affected.

If any transportation providers fail to deliver raw materials to us in a timely manner, we may be unable to manufacture products on a timely basis. Shipments of products and raw materials may be delayed due to weather conditions, strikes or other events. Any failure of a third-party transportation provider to deliver raw materials or products in a timely manner could harm our reputation, negatively affect our customer relationships and have a material adverse effect on our business, financial condition and results of operations.

We are dependent upon our key management personnel and critical talent whereby the loss of any of these persons could adversely affect our results of operations.

We are highly dependent upon key members of our management team along with critical talent possessing unique technical skills for the execution of our business plan. We believe that our future success is highly dependent on the contributions of these key employees. There can be no assurance that any individual will continue in his or her capacity for any particular period of time. The loss of any of these key employees could delay or prevent the achievement of our business objectives and have a material adverse effect upon our results of operations and financial position.

We and certain subsidiaries have indebtedness, which subjects us to potential defaults, could adversely affect our ability to raise additional capital to fund our operations and limits our ability to react to changes in the economy or the biodiesel industry.

At March 31, 2014, our total long-term debt was $25.56 million. This includes consolidated long-term debt owed by our Variable Interest Entities, or VIEs, including 416 South Bell, LLC, or Bell, LLC. In December 2011, certain of our subsidiaries entered into a revolving credit agreement with a bank group and Wells Fargo Capital Finance, LLC, which we refer to as the Wells Fargo Revolver. At March 31, 2014, there was $2.44 million outstanding under our lines of credit, all of which we guarantee.

All of the agreements for our indebtedness contain financial covenants the breach of which would result in an event of default by us or our subsidiary obligor. For a discussion of the financial covenants related to our debt agreements, see “Management’s discussion and analysis of financial condition and results of operations-Liquidity.”

Our subsidiaries are required annually to pay a certain portion of our excess cash flow at our Danville and Newton facilities to their respective lenders, which reduces the cash flow that we receive from these facilities.

Our indebtedness could:


•	require us to dedicate a substantial portion of our cash flow from operations to payments of principal, interest on, and other fees related to such indebtedness, thereby reducing the availability of our cash flow to fund working capital and capital expenditures, and for other general corporate purposes;


•	increase our vulnerability to general adverse economic and biodiesel industry conditions;


•	limit our flexibility in planning for, or reacting to, changes in our business and the biodiesel industry, which may place us at a competitive disadvantage compared to our competitors that have less debt; and


•	limit among other things, our ability to borrow additional funds.

We might require additional capital to support business growth, and this capital might not be available on acceptable terms, or at all.

We intend to continue to make investments to support our business growth and may require additional funds to respond to business challenges, including the need to develop our renewable chemicals business or expand or enhance our biodiesel operations or acquire complementary businesses and technologies. Accordingly, we may need to engage in equity or debt financing to secure additional funds. If we raise additional funds through further issuances of equity or convertible debt securities, our stockholders could suffer significant dilution, and any new equity securities we issue could have rights, preferences and privileges superior to those of holders of our common stock. Any debt financing could involve restrictive covenants, which may restrict our flexibility in operating our business and make it more difficult for us to obtain additional capital and to pursue business opportunities, including potential acquisitions. We may not be able to obtain additional financing on terms favorable to us, if at all. If we are unable to obtain adequate financing on terms satisfactory to us, when we require it, our ability to continue to support our business growth and to respond to business challenges could be significantly limited, and our business, operating results, financial condition and prospects could be adversely affected.

Our success depends on our ability to manage our growing and changing operations.

Since our formation, our business has grown significantly in size and complexity. This growth has placed, and is expected to continue to place, significant demands on our management, systems, internal controls and financial and physical resources.

In addition, we expect that we will need to further develop our financial and managerial controls and reporting systems to accommodate future growth. This will require us to incur expenses related to hiring additional qualified personnel, retaining professionals to assist in developing the appropriate control systems and expanding our information technology infrastructure. Our inability to manage growth effectively could have a material adverse effect on our results of operations, financial position and cash flows.

We have generated no revenue from sales of renewable chemicals to date and we face significant challenges to developing this business.

We have only recently entered the market for renewable chemicals with our acquisition of LS9, Inc.'s, or LS9, assets in January 2014. To date, we have not generated any revenues from this business which is still at a pre-commercial stage. In order to generate revenue from our renewable chemicals, we must be able to produce sufficient quantities of our products, which we have not done to date.

In entering this market, we intend to sell renewable chemicals as an alternative to chemicals currently in use, and in some cases the chemicals that we seek to replace have been used for many years. The potential customers for our renewable chemical products generally have well developed manufacturing processes and arrangements with suppliers of the chemical components of their products and may resist changing these processes and components. These potential customers frequently impose lengthy and complex product qualification procedures on their suppliers. Factors that these potential customers consider during the product qualification process include consumer preference, manufacturing considerations such as process changes and capital and other costs associated with transitioning to alternative components, supplier operating history, regulatory issues, product liability and other factors, many of which are unknown to, or not well understood by, us. Satisfying these processes may take many months or years. If we are unable to convince these potential customers that our products are comparable to the chemicals that they currently use or that the use of our products produces benefits to them, we will not be successful in these markets and our business will be adversely affected. Additionally, in contrast to the tax incentives relating to biofuels, tax credits and subsidies are not currently available in the United States for consumer products or chemical companies who use renewable chemical products. We do not expect meaningful revenue from our sale of renewable chemicals in the near term.

We may encounter difficulties in effectively integrating the businesses we acquire.

We may face significant challenges in effectively integrating entities and businesses that we acquire, including our acquisition of substantially all of LS9's assets in January 2014, as well as our pending acquisition of substantially all of Syntroleum Corporation's, or Syntroleum, assets and we may not realize the benefits anticipated from such acquisitions. Achieving the anticipated benefits of our acquired businesses will depend in part upon whether we can integrate our businesses in an efficient and effective manner. Our integration of acquired businesses involves a number of risks, including:


•	difficulty in integrating the operations and personnel of the acquired company;


•	difficulty in effectively integrating the acquired technologies, products or services with our current technologies, products or services;


•	demands on management related to the increase in our size after the acquisition;


•	the diversion of management’s attention from daily operations to the integration of acquired businesses and personnel;


•	failure to achieve expected synergies and costs savings;


•	difficulties in the assimilation and retention of employees;


•	difficulties in the assimilation of different cultures and practices, as well as in the assimilation of broad and geographically dispersed personnel and operations;


•	difficulties in the integration of departments, systems, including accounting systems, technologies, books and records and procedures, as well as in maintaining uniform standards and controls, including internal control over financial reporting, and related procedures and policies;


•	incurring acquisition-related costs or amortization costs for acquired intangible assets that could impact our operating results;


•	the need to fund significant working capital requirements of any acquired production facilities;

•

potential failure of the due diligence processes to identify significant problems, liabilities or other shortcomings or challenges of an acquired company or technology, including but not limited to, issues with the acquired company’s intellectual property, product quality, environmental liabilities, data back-up and security, revenue recognition or other accounting practices, employee, customer or partner issues or legal and financial contingencies;


•	exposure to litigation or other claims in connection with, or inheritance of claims or litigation risk as a result of, an acquisition, including but not limited to, claims from terminated employees, customers, former stockholders or other third parties; and


•	incurring significant exit charges if products or services acquired in business combinations are unsuccessful.

We have three partially constructed plants, one non-operational plant, and planned upgrades to our operating plants, each of which would require capital that we may not be able to raise and that may result in an impairment that could negatively impact our financial position, results of operations and future cash flows.

We have three partially constructed plants, one near New Orleans, Louisiana, one in Emporia, Kansas and one in Clovis, New Mexico and one non-operational plant near Atlanta, Georgia. We may choose to invest approximately $145 to $160 million in the aggregate, excluding working capital requirements, before these four plants would be able to commence production. Our Clovis plant is currently being operated as a terminal facility. In order to complete construction these facilities as planned, we will require additional capital. In November 2012, we acquired the above mentioned biodiesel facility near Atlanta, Georgia, which had been idled prior to our acquisition and will remain so until certain repairs or upgrades are made. While we intend to finance certain upgrades to our existing facilities from our cash flow from operations, we will need to raise significant capital to complete construction of the three partially constructed or non-operational facilities and to fund related working capital requirements. It is uncertain when or if financing will be available. It is also likely that the terms of any project financing would include customary financial and other covenants restricting our project subsidiaries, including restrictions on the ability to make distributions, to guarantee indebtedness and to incur liens on the plants of such subsidiaries.

We also may engage in acquisitions of assets or facilities in the future that require significant investment to complete or operate including our contemplated acquisition of substantially all of the assets of Syntroleum, which assets include a 50% membership interest in Dynamic Fuels, which owns a currently idled renewable diesel facility in Geismar, Louisiana. If we are unable to obtain such capital on satisfactory terms, or if such capital is otherwise unavailable, or if we encounter cost overruns on these projects such that we have insufficient capital, we may have to postpone completion of these projects indefinitely, which may adversely affect our ability to implement our strategy and our future revenues and future cash flows.

We may not successfully identify and complete acquisitions and other strategic relationships on favorable terms in order to execute our strategy to grow and diversify our business.

We regularly review domestic and international acquisitions of biofuel production facilities and have acquired most of our facilities from third parties. However, we may be unable to identify suitable acquisition candidates in the future. Even if we identify appropriate acquisition candidates, we may be unable to complete such acquisitions on favorable terms, if at all. If we are unable to successfully acquire other businesses or facilities, we may not be able to grow our business as planned.

In addition, one of our strategic goals is to expand our biodiesel production capabilities into international markets. In the event we expand our operations into international markets through acquisitions or otherwise, we may be exposed to additional risks, including unexpected changes in foreign laws and regulations, political and economic instability, challenges in managing foreign operations, increased costs to adapt our systems and practices to those used in foreign countries, export duties, currency fluctuations and restrictions, tariffs and other trade barriers, and the burdens of complying with a wide variety of foreign laws, each of which could have a material adverse effect on our business, financial condition, results of operations and liquidity.

We intend to pursue strategic initiatives to diversify our business that will require significant funding and management attention and these initiatives may not be successful.

We are seeking opportunities to diversify our product lines, as a commercialization partner for companies engaged in the development of new advanced biofuels, by using our biorefinery platform to produce renewable chemicals from bio-mass feedstocks and by entering entirely new industries through acquisitions or otherwise, including through our recent acquisition of substantially all the assets of LS9 in January 2014 and the contemplated acquisition of substantially all the assets of Syntroleum's later this year. There is no assurance that new technologies capable of economically producing advanced biofuels will be developed, that the developers of these technologies will select us as their commercialization partner or that the terms of any such collaborative arrangement will be favorable to us. Further, the renewable chemicals market is underdeveloped. Any chemicals that we produce from renewable sources may not prove to be as effective as chemicals produced from petroleum or other sources and, regardless of their effectiveness, renewable chemicals may not be accepted in the chemical marketplace. Furthermore, we may not be able to acquire companies in different industries at attractive valuations or at all. These strategic initiatives will require significant funding and management attention, and if we are not successful in implementing them, our financial condition and results of operations may be harmed.

Our business is subject to seasonal fluctuations, which are likely to cause our revenues and operating results to fluctuate.

Our operating results are influenced by seasonal fluctuations in the price of and demand for biodiesel. Our sales tend to decrease during the winter season due to perceptions that biodiesel will not perform adequately in colder weather. For example, the unseasonably cold winter recently experienced reduced demand. Colder seasonal temperatures can cause the higher cloud point biodiesel we make from inedible animal fats to become cloudy and eventually gel at a higher temperature than petroleum-based diesel or lower cloud point biodiesel made from soybean, canola, used cooking oil or inedible corn oil. Such gelling can lead to plugged fuel filters and other fuel handling and performance problems for customers and suppliers. Reduced demand in the winter for our higher cloud point biodiesel may result in excess supply of such higher cloud point biodiesel and lower prices for such higher cloud point biodiesel. In addition, most of our production facilities are located in colder Midwestern states and our costs of shipping biodiesel to warmer climates generally increase in cold weather months.

In addition, our RINs also have an element of seasonality to them. Since only 20% of an Obligated Party’s annual RVO can be satisfied by prior year RINs, most RINs must come from biofuel produced or imported during the RVO year. As a result, one would expect RIN prices to decrease as the calendar year progresses if the RIN market is oversupplied compared to that year’s RVO and increase if it is undersupplied. For example, in 2012, which had a RVO for biomass-based diesel of one billion gallons, biomass-based diesel RIN prices, as reported by OPIS, began to decrease in September when biomass-based diesel RIN generation neared the equivalent of 900 million gallons, as reported by EMTS. Similarly, in September of 2013 when biomass-based diesel RIN generation reached approximately 960 million gallons compared to a 2013 RVO of 1.28 billion gallons, biomass-based diesel RIN prices, as reported by OPIS, began to decline. As a result of these seasonal fluctuations, comparisons of operating measures between consecutive quarters may not be as meaningful as comparisons between longer reporting periods.

Failure to comply with governmental regulations, including EPA requirements relating to RFS2, could result in the imposition of penalties, fines, or restrictions on our operations and remedial liabilities.

The biodiesel industry is subject to extensive federal, state and local laws and regulations related to the general population’s health and safety and compliance and permitting obligations, including those related to the use, storage, handling, discharge, emission and disposal of municipal solid waste and other waste, pollutants or hazardous substances, discharges, air and other emissions, as well as land use and development. Existing laws also impose obligations to clean up contaminated properties or to pay for the cost of such remediation, often upon parties that did not actually cause the contamination. Compliance with these laws, regulations and obligations could require substantial capital expenditures. Failure to comply could result in the imposition of penalties, fines or restrictions on operations and remedial liabilities. These costs and liabilities could adversely affect our operations.

Changes in environmental laws and regulations occur frequently, and any changes that result in more stringent or costly waste handling, storage, transport, disposal or cleanup requirements could require us to make significant expenditures to attain and maintain compliance and may otherwise have a material adverse effect on our business in general and on our results of operations, competitive position or financial condition. We are unable to predict the effect of additional environmental laws and regulations which may be adopted in the future, including whether any such laws or regulations would significantly increase our cost of doing business or affect our operations in any area.

Under certain environmental laws and regulations, we could be held strictly liable for the removal or remediation of previously released materials or property contamination regardless of whether we were responsible for the release or contamination, or if current or prior operations were conducted consistent with accepted standards of practice. Such liabilities can be significant and, if imposed, could have a material adverse effect on our financial condition or results of operations.

In addition to the regulations mentioned above, we are subject to various laws and regulations related to RFS2, most significantly regulations related to the generation and dissemination of RINs. These regulations are highly complex and evolving, requiring us to periodically update our compliance systems. For example, in 2008, we unintentionally generated duplicate RINs as a result of a change to the software we use to manage RIN generation. We voluntarily reported this violation to the EPA and followed EPA guidance in correcting the issue promptly. In 2011, we entered into an administrative settlement agreement with the EPA regarding this violation and paid a fine for this inadvertent violation. Any violation of these regulations by us, inadvertently or otherwise, could result in significant fines and harm our customers’ confidence in the RINs we issue, either of which could have a material adverse effect on our business. For a detailed description of RINs, see “Business-Government Programs Favoring Biodiesel Production and Use-Renewable Identification Numbers.”

In response to certain cases of RIN fraud whereby biodiesel producers were selling biomass-based diesel RINs without having produced the required renewable fuel, the EPA is in the process of implementing a quality assurance program for RIN compliance. Compliance with these or any new regulations or Obligated Party verification procedures could require significant expenditures to attain and maintain compliance. Failure to comply could result in the imposition of penalties, fines, restrictions on operations, loss of customers and remedial liabilities. These costs and liabilities may have a material adverse effect on our

business in general and on our results of operations, competitive position or financial condition. We are unable to predict the effect of any additional regulatory or customer requirements which may be adopted in the future, including whether any such regulations or verification procedures would significantly increase our cost of doing business or affect our operations in any area.

Our business may suffer if we are unable to attract or retain talented personnel.

Our success depends on the abilities, expertise, judgment, discretion, integrity and good faith of our management and employees to manage the business and respond to economic, market and other conditions. We have a relatively small management team and employee base, and the inability to attract suitably qualified replacements or additional staff could adversely affect our business. No assurance can be given that our management team or employee base will continue their employment, or that replacement personnel with comparable skills could be found. If we are unable to attract and retain key personnel and additional employees, our business may be adversely affected.

If we fail to maintain effective internal control over financial reporting, we might not be able to report our financial results accurately or prevent fraud; in that case, our stockholders could lose confidence in our financial reporting, which would harm our business and could negatively impact the value of our stock.

Effective internal controls are necessary for us to provide reliable financial reports and prevent fraud. The process of maintaining our internal controls may be expensive and time consuming and may require significant attention from management. Although we have concluded as of March 31, 2014 that our internal control over financial reporting provides reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles, because of its inherent limitations, internal control over financial reporting may not prevent or detect fraud or misstatements. Failure to implement required new or improved controls, or difficulties encountered in their implementation, could harm our results of operations or cause us to fail to meet our reporting obligations. If we or our independent registered public accounting firm discover a material weakness, the disclosure of that fact could harm the value of our stock and our business.

A natural disaster, leak, fire or explosion at any of our production plants or customer’s facilities could increase our costs and liabilities.

Because biodiesel and some of its inputs and outputs are combustible and/or flammable, a leak, fire or explosion may occur at a plant or customer’s facility which could result in damage to the plant and nearby properties, injury to employees and others, and interruption of operations. In addition, our Houston facility, due to its coastal location, is vulnerable to hurricanes, which may cause plant damage, injury to employees and others and interruption of operations and all of our plants could incur damage from other natural disasters. A majority of our facilities are also located in the Midwest, which is subject to tornado activity. Furthermore, our REG Life Sciences, LLC, or REG Life Sciences, research and development center is in South San Francisco, California, which is subject to earthquakes. If any of the foregoing events occur, we may incur significant additional costs including, among other things, loss of profits due to unplanned temporary or permanent shutdowns of our facilities, clean-up costs, liability for damages or injuries, legal expenses and reconstruction expenses, which would seriously harm our results of operations and financial condition.

Our insurance may not protect us against our business and operating risks.

We maintain insurance for some, but not all, of the potential risks and liabilities associated with our business. For some risks, we may not obtain insurance if we believe the cost of available insurance is excessive relative to the risks presented. As a result of market conditions, premiums and deductibles for certain insurance policies can increase substantially and, in some instances, certain insurance policies may become unavailable or available only for reduced amounts of coverage. As a result, we may not be able to renew our existing insurance policies or procure other desirable insurance on commercially reasonable terms, if at all. Although we intend to maintain insurance at levels we believe are appropriate for our business and consistent with industry practice, we will not be fully insured against all risks. In addition, pollution, environmental risks and the risk of natural disasters generally are not fully insurable. Losses and liabilities from uninsured and underinsured events and delay in the payment of insurance proceeds could have a material adverse effect on our financial condition and results of operations.

Confidentiality agreements with employees and others may not adequately prevent disclosures of confidential information, trade secrets and other proprietary information.

We rely in part on trade secret protection to protect our confidential and proprietary information and processes. However, trade secrets are difficult to protect. We have taken measures to protect our trade secrets and proprietary information, but these measures may not be effective. For example, we require new employees and consultants to execute confidentiality agreements upon the commencement of their employment or consulting arrangement with us. These agreements generally require that all confidential information developed by the individual or made known to the individual by us during the course of the individual’s relationship with us be kept confidential and not disclosed to third parties. These agreements also generally provide that knowhow and inventions conceived by the individual in the course of rendering services to us are our exclusive property.

Nevertheless, these agreements may be breached, or may not be enforceable, and our proprietary information may be disclosed. Further, despite the existence of these agreements, third parties may independently develop substantially equivalent proprietary information and techniques. Accordingly, it may be difficult for us to protect our trade secrets. Costly and time-consuming litigation could be necessary to enforce and determine the scope of our proprietary rights, and failure to obtain or maintain trade secret protection could adversely affect our competitive business position.

Moreover, we cannot assure you that our technology does not infringe upon any valid claims of patents that other parties own. In the future, if we are found to be infringing on a patent owned by a third party, we might have to seek a license from such third party to use the patented technology. We cannot assure you that, if required, we would be able to obtain such a license on terms acceptable to us, if at all. If a third party brought a legal action against us or our licensors, we could incur substantial costs in defending ourselves, and we cannot assure you that such an action would be resolved in our favor. If such a dispute were to be resolved against us, we could be subject to significant damages.

We are a holding company and there are limitations on our ability to receive dividends and distributions from our subsidiaries.

All of our principal assets, including our biodiesel production facilities, are owned by subsidiaries and some of these subsidiaries are subject to loan covenants that generally restrict them from paying dividends, making distributions or making loans to us or to any other subsidiary. These limitations will restrict our ability to repay indebtedness, finance capital projects or pay dividends to stockholders from our subsidiaries’ cash flows from operations.

In the event we enter into new construction contracts, we may be exposed to a variety of risks that could affect our ability to realize profit.

While our construction services management business has had only limited external operations over the last three years, we intend to continue to pursue opportunities to provide these services. Substantially all of our revenues from our new facility construction services business have been derived from fixed unit price contracts. Fixed unit price contracts require us to perform the contract for a fixed unit price irrespective of our actual costs. As a result, we realize a profit on these contracts only if we and our subcontractors successfully estimate our costs and then successfully control actual costs and avoid cost overruns. Further, we have historically subcontracted substantially all of our construction work to various engineering and construction companies on a time and materials, rather than fixed, basis. As a result, we have less control over the largest component of our plant construction costs and the risk of cost overruns generally falls on us rather than our subcontractors. If we or our subcontractors do not perform a contract within cost estimates, then cost overruns may cause us to incur losses or cause the contract not to be as profitable as we initially expected. This, in turn, could negatively affect our cash flow, earnings and financial position. As we have acquired assets and begun consolidating the industry, our construction services management business has almost exclusively been focused on internal intercompany projects.

If we or our subcontractors perform extra or change order work that is not approved by the customer in advance we may have a dispute with the customer over whether the work performed is beyond the scope of the work included in the original project plans and specifications or, if the customer agrees that the work performed qualifies as extra work, the price that the customer is willing to pay for the extra work. These disputes may result in us not receiving payment for all or a significant portion of work that we or our subcontractors have performed. Even where the customer agrees to pay for the extra work, we may be required to fund the cost of that work for a lengthy period of time until the change order is approved and paid by the customer. To the extent actual recoveries with respect to change orders or amounts subject to contract disputes or claims are less than the estimates used in our financial statements, the amount of any shortfall will reduce our revenues and profits, and this could have a material adverse effect on our working capital and results of operations.

Risks Related to the Biodiesel Industry

The market price of biodiesel is influenced by the price of petroleum-based distillate fuels, such as ultra-low sulfur diesel, and decreases in the price of petroleum-based distillate fuels or RIN values would very likely decrease the price we can charge for our biodiesel, which could harm our revenues and profitability.

Historically, biodiesel prices have been strongly correlated to petroleum-based diesel prices and in particular ULSD, regardless of the cost of producing biodiesel itself. We market our biofuel as an alternative to petroleum-based fuels. Therefore, if the price of petroleum-based diesel falls, the price of biodiesel could decline, and we may be unable to produce products that are an economically viable alternative to petroleum-based fuels. Petroleum prices are volatile due to global factors, such as the impact of wars, political uprisings, OPEC production quotas, worldwide economic conditions, changes in refining capacity and natural disasters. Additionally, demand for liquid transportation fuels, including biodiesel, is impacted by economic conditions.

Just as a small reduction in the real or anticipated supply of crude oil can have a significant upward impact on the price of petroleum-based fuels, a perceived reduction of such threats can result in a significant reduction in petroleum-based fuel prices.

A reduction in petroleum-based fuel prices may have a material adverse effect on our revenues and profits if such price decrease reduces the price we are able to charge for our biodiesel.

There was a sharp decline in RIN prices during third quarter 2012 that carried through the end of 2012. During this period, RIN pricing declined from $1.17 per RIN at June 30, 2012 to $0.64 per RIN at December 31, 2012, as reported by OPIS, which contributed to the decline in price of biodiesel. RIN prices also declined sharply from $1.09 per RIN on July 1, 2013 to $0.35 per RIN at December 31, 2013, as reported by OPIS. A reduction in RIN values, such as those experienced in the second half of 2012 and 2013, may have a material adverse effect on our revenues and profits as such price decrease reduce the price we are able to charge for our biodiesel.

We operate in a highly competitive industry and competition in our industry would increase if new participants enter the biodiesel or biomass-based diesel business.

We operate in a very competitive environment. The biodiesel industry is primarily comprised of smaller entities that engage exclusively in biodiesel production, large integrated agribusiness companies that produce biodiesel along with their soybean crush businesses and increasingly, integrated petroleum companies. We face competition for capital, labor, feedstocks and other resources from these companies. In the United States, we compete with soybean processors and refiners, including Archer-Daniels-Midland Company, LLC, Cargill, Inc. and Louis Dreyfus Commodities. In addition, petroleum refiners are increasingly entering into biodiesel and renewable diesel production, includes Neste Oil with approximately 600 million gallons of global renewable diesel production capacity in Asia and Europe and Valero Energy Corporation with its Diamond Green joint venture renewable diesel plant. These and other competitors that are divisions of larger enterprises may have greater financial resources than we do. We also have many smaller competitors. If our competitors consolidate or otherwise grow and we are unable to similarly increase our scale, our business and prospects may be significantly and adversely affected.

In addition, petroleum companies and diesel retailers form the primary distribution networks for marketing biodiesel through blended petroleum-based diesel. If these companies increase their direct or indirect biodiesel and renewable diesel production, there will be less need to purchase biodiesel from independent biodiesel producers like us. Such a shift in the market would materially harm our operations, cash flows and financial position.

The development of alternative fuels and energy sources may reduce the demand for biodiesel, resulting in a reduction in our revenues and profitability.

The development of alternative fuels, including a variety of energy alternatives to biodiesel has attracted significant attention and investment. Neste Oil operates four renewable diesel plants: a 240 million gallon per year plant in Singapore, a 240 million gallon per year plant in Rotterdam, Netherlands, and two 60 million gallon per year plants in Porvoo, Finland. Diamond Green Diesel, LLC has completed construction and commenced operations of its 137 million gallon per year renewable diesel plant in Norco, Louisiana in 2013. Under RFS2, renewable diesel made from biomass meets the definition of biomass-based diesel and thus is eligible, along with biodiesel, to satisfy the RFS2 biomass-based diesel requirement described in “Business-Government Programs Favoring Biodiesel Production and Use.” Furthermore, under RFS2, renewable diesel may receive up to 1.7 RINs per gallon, whereas biodiesel currently receives 1.5 RINs per gallon. For a detailed description of RINs and RIN values, see “Business-Government Programs Favoring Biodiesel Production and Use-Renewable Identification Numbers.” As the value of RINs increases, this 0.2 RIN advantage may make renewable diesel more cost-effective, both as a petroleum-based diesel substitute and for meeting RFS2 requirements. If renewable diesel proves to be more cost-effective than biodiesel, our revenues and results of operations would be adversely impacted.

In addition, the EPA may allow other fuels to satisfy the RFS2 requirements and allow RINs to be generated upon the production of these fuels. The EPA recently adopted regulations to amend the definition of “Home Heating Oil” under RFS2, which expands the scope of fuels eligible to generate RINs. This will increase competition within heating oil markets by introducing fuels that could generate more RINs (i.e., cellulosic diesel) and may be more cost competitive than biodiesel utilized as heating oil.

The biodiesel industry will also face increased competition resulting from the advancement of technology by automotive, industrial and power generation manufacturers which are developing more efficient engines, hybrid engines and alternative clean power systems. Improved engines and alternative clean power systems offer a technological solution to address increasing worldwide energy costs, the long-term availability of petroleum reserves and environmental concerns. If and when these clean power systems are able to offer significant efficiency and environmental benefits and become widely available, the biodiesel industry may not be able to compete effectively with these technologies and government requirements for the use of biodiesel may not continue.

The development of alternative fuels and renewable chemicals also puts pressure on feedstock supply and availability to the biodiesel industry. If these emerging technologies compete with biodiesel for feedstocks, are more profitable or have greater governmental support than biodiesel does, then the biodiesel industry may have difficulty in procuring the feedstocks necessary to be successful.

Increased industry-wide production of biodiesel could have a negative effect on our margins and there remains excess production capacity in the biodiesel industry.

According to EPA EMTS data, approximately 1.1 billion gallons of biomass-based diesel RINs were generated in the United States in 2011, 1.14 billion gallons were generated in 2012, 1.78 billion gallons were generated in 2013, and 0.33 billion gallons for the three months ended March 31, 2014. Such production was in excess of the 800 million gallon RFS2 requirement for 2011, the one billion gallon requirement for 2012, and the 1.28 billion gallon requirement for 2013. Should biodiesel production continue to remain above RFS2 required volumes, the resulting supply could put downward pressure on our margins for biodiesel, negatively affecting our profitability. Under RFS2, Obligated Parties are entitled to satisfy up to 20% of their annual volume requirement for any given year with gallons used in the previous year so long as they are in compliance with the RFS2.

In 2013, 1.78 billion gallons of biomass-based diesel RINs were generated. Adding the 2012 carry-over to the 2013 RIN generation, would result in an estimated total biomass-based diesel RIN availability of approximately 2.04 billion gallons, which is approximately 760 million gallons more than required to satisfy the 1.28 billion gallon 2013 biomass-based diesel RVO. The proposed 2014 biomass-based diesel RVO is 1.28 billion gallons, and if adopted would limit the 2014 carryover to 256 million gallons, or 20% of 1.28 billion, thus resulting in an excess supply of 504 million gallons of biomass-based diesel RINs. These excess RINs can be used to fulfill the advanced biofuel RVO or the renewable fuel RVO. If the volume of excess biomass-based diesel RINs exceeds the volume the Obligated Parties desire to use to fulfill their advanced biofuel and renewable fuel requirements, the demand for and price of our biodiesel and biomass-based diesel RINs may be reduced, which could harm its revenues and cash flows. Many biodiesel plants in the United States do not currently operate, and of those that do, many do not operate at full capacity. According to the National Biodiesel Board, or NBB, as of September 12, 2012, 2.7 billion gallons per year of biodiesel production capacity in the United States were registered under the RFS2 program by NBB members. In addition to this amount, several hundred more gallons of U.S. based biomass-based diesel production capacity was registered by non-NBB members and another 1.2 billion gallons of biomass-based diesel production was registered by foreign producers. Furthermore, plants under construction and expansion in the United States as of December 31 2011, if completed, could add an additional several hundred million gallons of annual biodiesel production capacity. The annual production capacity of existing plants and plants under construction far exceeds both historic consumption of biodiesel in the United States and required consumption under RFS2. If this excess production capacity was fully utilized for the U.S. market, it would increase competition for our feedstocks, increase the volume of biomass-based diesel on the market and may reduce biodiesel gross margins, harming our revenues and profitability.

The European Commission has imposed anti-dumping and countervailing duties on biodiesel blends imported into Europe, which have effectively eliminated our ability to sell those biodiesel blends in Europe.

In March 2009, as a response to the BTC, the European Commission imposed anti-dumping and anti-subsidy tariffs on biodiesel produced in the United States. These tariffs have effectively eliminated European demand for 20% biodiesel blends, or B20, or higher imported from the United States. The European Commission has extended these tariffs through 2014. In May 2011, the European Commission imposed similar anti-dumping and countervailing duties on biodiesel blends below B20. These duties significantly increase the price at which we and other United States biodiesel producers will be able to sell such biodiesel blends in European markets, making it difficult or impossible to compete in the European biodiesel market. These anti-dumping and countervailing duties therefore decrease the demand for biodiesel produced in the United States and increase the supply of biodiesel available in the United States market. Such market dynamics may negatively impact our revenues and profitability.

If automobile manufacturers and other industry groups express reservations regarding the use of biodiesel, our ability to sell biodiesel will be negatively impacted.

Because it is a relatively new product compared with petroleum diesel, research on biodiesel use in automobiles is ongoing. While most heavy duty automobile manufacturers have approved blends of up to 20% biodiesel, some industry groups have recommended that blends of no more than 5% biodiesel be used for automobile fuel due to concerns about fuel quality, engine performance problems and possible detrimental effects of biodiesel on rubber components and other engine parts. Although some manufacturers have encouraged use of biodiesel fuel in their vehicles, cautionary pronouncements by other manufacturers or industry groups may impact our ability to market our biodiesel.

Perception about “food vs. fuel” could impact public policy which could impair our ability to operate at a profit and substantially harm our revenues and operating margins.

Some people believe that biodiesel may increase the cost of food, as some feedstocks such as soybean oil used to make biodiesel can also be used for food products. This debate is often referred to as “food vs. fuel.” This is a concern to the biodiesel industry because biodiesel demand is heavily influenced by government policy and if public opinion were to erode, it is possible that these policies would lose political support. These views could also negatively impact public perception of

biodiesel. Such claims have led some, including members of Congress, to urge the modification of current government policies which affect the production and sale of biofuels in the United States.

Concerns regarding the environmental impact of biodiesel production could affect public policy which could impair our ability to operate at a profit and substantially harm our revenues and operating margins.

Under the EISA, the EPA is required to produce a study every three years of the environmental impacts associated with current and future biofuel production and use, including effects on air and water quality, soil quality and conservation, water availability, energy recovery from secondary materials, ecosystem health and biodiversity, invasive species and international impacts. The first such triennial report was released in February 2012. The 2012 report concludes that (1) the extent of negative impacts to date are limited in magnitude and are primarily associated with the intensification of corn production; (2) whether future impacts are positive or negative will be determined by the choice of feedstock, land use change, cultivation and conservation practices; and (3) realizing potential benefits will require implementation and monitoring of conservation and best management practices, improvements in production efficiency, and implementation of innovative technologies at commercial scales. Should future EPA triennial studies, or other analyses find that biofuel production and use has resulted in, or could in the future result in, adverse environmental impacts, such findings could also negatively impact public perception of biofuel and acceptance of biofuel as an alternative fuel, which also could result in the loss of political support.

To the extent that state or federal laws are modified or public perception turns against biodiesel, use requirements such as RFS2 and state tax incentives may not continue, which could materially harm our ability to operate profitably.

Problems with product performance, in cold weather or otherwise, could cause consumers to lose confidence in the reliability of biodiesel which, in turn, would have an adverse impact on our ability to successfully market and sell biodiesel.

Concerns about the performance of biodiesel could result in a decrease in customers and revenues and an unexpected increase in expenses. Biodiesel typically has a higher cloud point than petroleum-based diesel. The cloud point is the temperature below which a fuel exhibits a noticeable cloudiness and is the conventional indicator of a fuel’s potential for cold weather problems. The lower the cloud point, the better the fuel should perform in cold weather. According to an article published by Iowa State University Extension, the cloud point of biodiesel is typically between 30 °F and 60 °F, while the cloud point of the most common form of pure petroleum-based diesel fuel is typically less than 20 °F. It is our experience that when biodiesel is mixed with pure petroleum-based diesel to make a two percent biodiesel blend, the cloud point of the blended fuel can be 2 °F to 6 °F higher than petroleum-based diesel and the cloud point of a twenty percent biodiesel blend can be 15 °F to 35 °F higher than petroleum based diesel, depending on the individual cloud points of the biodiesel and petroleum-based diesel. Cold temperatures can therefore cause biodiesel blended fuel to become cloudy and eventually to gel when pure petroleum-based diesel would not, and this can lead to plugged fuel filters and other fuel handling and performance problems for customers and suppliers. The consequences of these higher cloud points may cause demand for biodiesel in northern and eastern United States markets to diminish during the colder months, which are the primary markets in which we currently operate.

The tendency of biodiesel to gel in colder weather may also result in long-term storage problems. In cold climates, fuel may need to be stored in a heated building or heated storage tanks, which result in higher storage costs. This and other performance problems, including the possibility of particulate formation above the cloud point of a blend of biodiesel and petroleum-based diesel, may also result in increased expenses as we try to remedy these performance problems, including the costs of extra cold weather treatment additives. Remedying these performance problems may result in decreased yields, lower process throughput or both, as well as substantial capital costs. Any reduction in the demand for our biodiesel product, or the production capacity of our facilities will reduce our revenues and have an adverse effect on our cash flows and results of operations.

Growth in the sale and distribution of biodiesel is dependent on the expansion of related infrastructure which may not occur on a timely basis, if at all, and our operations could be adversely affected by infrastructure limitations or disruptions.

Growth in the biodiesel industry depends on substantial development of infrastructure for the distribution of biodiesel. Substantial investment required for these infrastructure changes and expansions may not be made on a timely basis or at all. The scope and timing of any infrastructure expansion are generally beyond our control. Also, we compete with other biofuel companies for access to some of the key infrastructure components such as pipeline and terminal capacity. As a result, increased production of biodiesel or other biofuels will increase the demand and competition for necessary infrastructure. Any delay or failure in expanding distribution infrastructure could hurt the demand for or prices of biodiesel, impede delivery of our biodiesel, and impose additional costs, each of which would have a material adverse effect on our results of operations and financial condition. Our business will be dependent on the continuing availability of infrastructure for the distribution of increasing volumes of biodiesel and any infrastructure disruptions could materially harm our business.

We face competition from imported biodiesel and renewable diesel, which may reduce demand for biodiesel produced by us and cause our revenues and profits to decline.

Biodiesel and renewable diesel imports into the United States have increased significantly and compete with United States produced biodiesel. The imported fuels may benefit from production incentives or other financial incentives in their home countries that offset some of their production costs and enable them to profitably sell biodiesel or renewable diesel in the United States at lower prices than United States-based biodiesel producers. Under RFS2, imported biodiesel and renewable diesel is eligible and, therefore, competes to meet the volumetric requirements for biomass-based diesel and advanced biofuels. If imports continue to increase, this could make it more challenging for us to market or sell biodiesel in the United States, which would have a material adverse effect on our revenues. Imported biodiesel that does not qualify under RFS2, also competes in jurisdictions where there are biodiesel blending requirements.

Nitrogen oxide emissions from biodiesel may harm its appeal as a renewable fuel and increase costs.

In some instances, biodiesel may increase emissions of nitrogen oxide as compared to petroleum-based diesel fuel, which could harm air quality. Nitrogen oxide is a contributor to ozone and smog. New Technology Diesel Engines eliminate any such increase. Emissions from older vehicles while the fleet turns over may decrease the appeal of biodiesel to environmental groups and agencies who have been historic supporters of the biodiesel industry, potentially harming our ability to market our biodiesel.

In addition, several states may act to regulate potential nitrogen oxide emissions from biodiesel. California is in the process of formulating biodiesel regulations that may limit the volume of biodiesel that can be used or require an additive to reduce potential emissions. In states where such an additive is required to sell biodiesel, the additional cost of the additive may make biodiesel less profitable or make biodiesel less cost competitive against petroleum-based diesel or renewable diesel, which would negatively impact our ability to sell our products in such states and therefore have an adverse effect on our revenues and profitability.

Several biofuels companies throughout the United States have filed for bankruptcy over the last several years due to industry and economic conditions.

A volatile regulatory environment, lack of debt or equity investments and volatile biofuel prices and feedstock costs have likely contributed to the necessity of bankruptcy filings by biofuel producers. Our business has been, and in the future may be, negatively impacted by the industry conditions that influenced the bankruptcy proceedings of other biofuel producers, or we may encounter new competition from buyers of distressed biodiesel properties who enter the industry at a lower cost than original plant investors.

Risks Related to Our Common Stock

The market price for our common stock may be volatile.

Although there is currently an active and liquid trading market for our common stock, the market price for our common stock is likely to be highly volatile and subject to wide fluctuations in response to factors including the following:


•	actual or anticipated fluctuations in our financial condition and operating results;


•	changes in the performance or market valuations of other companies engaged in our industry;


•	issuance of new or updated research reports by securities or industry analysts;


•	changes in financial estimates by us or of securities or industry analysts;


•	investors’ general perception of us and the industry in which we operate;


•	changes in the political climate in the industry in which we operate, existing laws, regulations and policies applicable to our business and products, including RFS2, and the continuation or adoption or failure to continue or adopt renewable energy requirements and incentives, including the BTC;


•	other regulatory developments in our industry affecting us, our customers or our competitors;


•	announcements of technological innovations by us or our competitors;


•	announcement or expectation of additional financing efforts, including sales or expected sales of additional common stock;


•	additions or departures of key management or other personnel;


•	litigation;


•	inadequate trading volume;


•	general market conditions in our industry; and


•	general economic and market conditions, including continued dislocations and downward pressure in the capital markets.

In addition, stock markets generally and from time to time experience significant price and volume fluctuations that are not related to the operating performance of particular companies. These market fluctuations may have material adverse effect on the market price of our common stock.

We may issue additional common stock as consideration for future investments or acquisitions.

We have issued in the past, and may issue in the future, our securities in connection with investments and acquisitions. The amount of our common stock or securities convertible into or exchangeable for our common stock issued in connection with an investment or acquisition could constitute a material portion of our then outstanding common stock.

We have never paid dividends on our common stock and we do not anticipate paying any cash dividends in the foreseeable future.

We have paid no cash dividends on any of our classes of common stock to date, have contractual restrictions against paying cash dividends and currently intend to retain our future earnings to fund the development and growth of our business. As a result, stockholders must look solely to appreciation of our common stock to realize a gain on their investment. This appreciation may not occur. Investors seeking cash dividends should not invest in our common stock.

Delaware law and our amended and restated certificate of incorporation and bylaws will contain anti-takeover provisions that could delay or discourage takeover attempts that stockholders may consider favorable.

Provisions in our amended and restated certificate of incorporation and bylaws may have the effect of delaying or preventing a change of control or changes in our management. These provisions include the following:


•	the right of the board of directors to elect a director to fill a vacancy created by the expansion of the board of directors;


•	the requirement for advance notice for nominations for election to the board of directors or for proposing matters that can be acted upon at a stockholders’ meeting;


•	the ability of the board of directors to alter our bylaws without obtaining stockholder approval;


•	the ability of the board of directors to issue, without stockholder approval, up to 10,000,000 shares of preferred stock with rights set by the board of directors, which rights could be senior to those of common stock;


•	a classified board;


•	the required approval of holders of at least two-thirds of the shares entitled to vote at an election of directors to adopt, amend or repeal our bylaws or amend or repeal the provisions of our amended and restated certificate of incorporation regarding the classified board, the election and removal of directors and the ability of stockholders to take action by written consent; and


•	the elimination of the right of stockholders to call a special meeting of stockholders and to take action by written consent.

In addition, because we are incorporated in Delaware, we are governed by the provisions of Section 203 of the Delaware General Corporation Law, or DGCL. These provisions may prohibit or restrict large stockholders, in particular those owning 15% or more of our outstanding voting stock, from merging or combining with us. These provisions in our amended and restated certificate of incorporation and bylaws and under Delaware law could discourage potential takeover attempts and could reduce the price that investors might be willing to pay for shares of our common stock in the future and result in our market price being lower than it would without these provisions.

If securities or industry analysts issue an adverse or misleading opinion regarding our stock or do not publish research or reports about our business, our stock price and trading volume could decline.

The trading market for our Common Stock relies in part on the research and reports that equity research analysts publish about us and our business. It is difficult for companies such as ours to attract independent equity research analysts to cover our common stock. We do not control these analysts or the content and opinions included in their reports. The price of our common stock could decline if one or more equity research analysts downgrade our common stock or if those analysts issue other unfavorable commentary or cease publishing reports about us or our business. Although there is currently an active and liquid trading market for REG common stock, if one or more equity research analysts ceases coverage of our company, we could lose visibility in the market, which in turn could cause our stock price to decline and the market for our common stock to become illiquid.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OR PROCEEDS

None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

None.

ITEM 6. EXHIBITS

(A) Exhibits:



Exhibit No.		Description
10.1		Biodiesel purchase agreement by and between the Company and Pilot Travel Center LLC †
31.1		Certification of the Chief Executive Officer pursuant to Rule 13a-14(a)/15d-14(a).
31.2		Certification of the Chief Financial Officer pursuant to Rule 13a-14(a)/15d-14(a).
32.1*		Certification of the Chief Executive Officer pursuant to 18 USC Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2*		Certification of the Chief Financial Officer pursuant to 18 USC Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101.INS		XBRL Instance Document
101.SCH		XBRL Taxonomy Extension Schema Document
101.CAL		XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF		XBRL Taxonomy Extension Definition Linkbase Document
101.LAB		XBRL Taxonomy Extension Label Linkbase Document
101.PRE		XBRL Taxonomy Extension Presentation Linkbase Document

* In accordance with Item 601(b)(32)(ii) of Regulation S-K and SEC Release No. 34-47986, the certifications furnished in Exhibit 32.1 and Exhibit 32.2 hereto are deemed to accompany this Form 10-Q and will not be deemed “filed” for purposes of Section 18 of the Exchange Act. Such certifications will not be deemed to be incorporated by reference into any filing under the Securities Act or the Exchange Act.

† Confidential treatment requested.

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.




	RENEWABLE ENERGY GROUP, INC.


Dated: May 9, 2014	By:	/s/ Daniel J. Oh
		Daniel J. Oh
		Chief Executive Officer (Principal Executive Officer)

Dated: May 9, 2014	By:	/s/ Chad Stone
		Chad Stone
		Chief Financial Officer (Principal Financial Officer)

Dated: May 9, 2014	By:	/s/ Chad A. Baker
		Chad A. Baker
		Controller and Chief Accounting Officer (Principal Accounting Officer)