10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended September 30, 2017

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

For the transition period from ______ to _______

Commission File Number 000-21467

 

(Exact name of registrant as specified in its charter)

Delaware (State or other jurisdiction of incorporation or organization)	41-2170618 (I.R.S. Employer Identification No.)
400 Capitol Mall, Suite 2060, Sacramento, California (Address of principal executive offices)	95814 (zip code)

(916) 403-2123
(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 x No o

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

Yes x No o

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

o Large accelerated filer	x Accelerated filer
o Non-accelerated filer (Do not check if a smaller reporting company)	o Smaller reporting company
o Emerging growth company

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

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

Yes o No x

As of November 8, 2017, there were 43,970,775 shares of Pacific Ethanol, Inc. common stock, $0.001 par value per share, and 896 shares of Pacific Ethanol, Inc. non-voting common stock, $0.001 par value per share, outstanding.

		Page
ITEM 1.	FINANCIAL STATEMENTS.
	Consolidated Balance Sheets as of September 30, 2017 (unaudited) and December 31, 2016	3
	Consolidated Statements of Operations for the Three and Nine Months Ended September 30, 2017 and 2016 (unaudited)	5
	Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 2017 and 2016 (unaudited)	6
	Notes to Consolidated Financial Statements (unaudited)	7
ITEM 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.	18
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.	28
ITEM 4.	CONTROLS AND PROCEDURES.	29
PART II
OTHER INFORMATION
ITEM 1.	LEGAL PROCEEDINGS.	31
ITEM 1A.	RISK FACTORS.	31
ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS.	39
ITEM 3.	DEFAULTS UPON SENIOR SECURITIES.	40
ITEM 4.	MINE SAFETY DISCLOSURES.	40
ITEM 5.	OTHER INFORMATION.	40
ITEM 6.	EXHIBITS.	41
SIGNATURES		43

2

PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS.

PACIFIC ETHANOL, INC.
CONSOLIDATED BALANCE SHEETS
(in thousands)

	September 30,		December 31,
	2017		2016
	(unaudited)		*
ASSETS
Current Assets:
Cash and cash equivalents	$	56,923	$	68,590
Accounts receivable, net (net of allowance for doubtful accounts of $18 and $331, respectively)		72,282		86,275
Inventories		71,819		60,070
Prepaid inventory		5,622		9,946
Income tax receivables		129		5,730
Derivative instruments		3,017		978
Other current assets		3,026		3,612
Total current assets		212,818		235,201
Property and equipment, net		509,369		465,190
Other Assets:
Intangible assets, net		2,678		2,678
Other assets		5,785		5,169
Total other assets		8,463		7,847
Total Assets	$	730,650	$	708,238

_______________

*       Amounts derived from the audited consolidated financial statements for the year ended December 31, 2016.

See accompanying notes to consolidated financial statements.

3

PACIFIC ETHANOL, INC.
CONSOLIDATED BALANCE SHEETS (CONTINUED)
(in thousands, except par value)

	September 30,			December 31,
	2017			2016
	(unaudited)			*
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities:
Accounts payable – trade	$	41,178		$	37,051
Accrued liabilities		22,245			20,280
Current portion – capital leases		799			794
Current portion – long-term debt		20,000			10,500
Derivative instruments		2,755			4,115
Accrued PE Op Co. purchase		3,828			3,828
Other current liabilities		1,591			2,273
Total current liabilities		92,396			78,841
Long-term debt, net of current portion		220,304			188,028
Capital leases, net of current portion		134			547
Warrant liabilities at fair value		–			651
Other liabilities		20,915			21,910
Total Liabilities		333,749			289,977
Commitments and Contingencies (Note 8)
Stockholders’ Equity:
Pacific Ethanol, Inc. Stockholders’ Equity:
Preferred stock, $0.001 par value; 10,000 shares authorized;
Series A: 1,684 shares authorized; no shares issued and outstanding as of September 30, 2017 and December 31, 2016;		–			–
Series B: 1,581 shares authorized; 927 shares issued and outstanding as of September 30, 2017 and December 31, 2016; liquidation preference of $18,075 as of September 30, 2017		1			1
Common stock, $0.001 par value; 300,000 shares authorized; 43,971 and 39,772 shares issued and outstanding as of September 30, 2017 and December 31, 2016, respectively		44			40
Non-voting common stock, $0.001 par value; 3,553 shares authorized; 1 and 3,540 shares issued and outstanding as of September 30, 2017 and December 31, 2016, respectively		–			4
Additional paid-in capital		926,248			922,698
Accumulated other comprehensive loss		(2,620	)		(2,620	)
Accumulated deficit		(554,858	)		(532,233	)
Total Pacific Ethanol, Inc. Stockholders’ Equity		368,815			387,890
Noncontrolling interests		28,086			30,371
Total Stockholders’ Equity		396,901			418,261
Total Liabilities and Stockholders’ Equity	$	730,650		$	708,238

_______________

*       Amounts derived from the audited consolidated financial statements for the year ended December 31, 2016.

See accompanying notes to consolidated financial statements.

4

PACIFIC ETHANOL, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS

(unaudited, in thousands, except per share data)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Net sales	$	445,442		$	417,806		$	1,236,984		$	1,183,039
Cost of goods sold		433,377			411,442			1,229,039			1,157,902
Gross profit		12,065			6,364			7,945			25,137
Selling, general and administrative expenses		8,720			5,971			22,932			20,436
Income (loss) from operations		3,345			393			(14,987	)		4,701
Fair value adjustments		–			(69	)		473			(53	)
Interest expense, net		(3,826	)		(3,874	)		(9,157	)		(16,643	)
Other income (expense), net		(60	)		32			(293	)		92
Loss before provision (benefit) for income taxes		(541	)		(3,518	)		(23,964	)		(11,903	)
Provision (benefit) for income taxes		–			–			–			(245	)
Consolidated net loss		(541	)		(3,518	)		(23,964	)		(11,658	)
Net loss attributed to noncontrolling interests		339			–			2,285			–
Net loss attributed to Pacific Ethanol, Inc.	$	(202	)	$	(3,518	)	$	(21,679	)	$	(11,658	)
Preferred stock dividends	$	(319	)	$	(319	)	$	(946	)	$	(949	)
Net loss available to common stockholders	$	(521	)	$	(3,837	)	$	(22,625	)	$	(12,607	)
Net loss per share, basic and diluted	$	(0.01	)	$	(0.09	)	$	(0.53	)	$	(0.30	)
Weighted-average shares outstanding, basic and diluted		42,475			42,226			42,358			42,156

See accompanying notes to consolidated financial statements.

5

PACIFIC ETHANOL, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
(unaudited, in thousands)

	Nine Months Ended September 30,
	2017			2016
Operating Activities:
Consolidated net loss	$	(23,964	)	$	(11,658	)
Adjustments to reconcile consolidated net loss to net cash provided by operating activities:
Depreciation and amortization of intangibles		28,486			26,526
Interest expense added to term debt		–			9,451
Fair value adjustments		(473	)		53
Amortization of debt discount		454			930
Amortization of deferred financing fees		339			97
Non-cash compensation		2,985			1,888
Loss (gain) on derivative instruments		836			(1,669	)
Bad debt expense		4			325
Changes in operating assets and liabilities, net of effects from acquisition of ICP:
Accounts receivable		25,625			(7,803	)
Inventories		(1,891	)		(4,168	)
Prepaid expenses and other assets		2,197			5,503
Prepaid inventory		4,397			(1,657	)
Accounts payable and accrued expenses		(3,995	)		(2,789	)
Net cash provided by operating activities		35,000			15,029
Investing Activities:
Additions to property and equipment		(12,348	)		(14,045	)
Purchase of ICP, net of cash acquired		(28,921	)		–
Proceeds from cash collateralized letters of credit		–			4,113
Net cash used in investing activities		(41,269	)		(9,932	)
Financing Activities:
Net (payments) proceeds from Kinergy’s line of credit		(5,889	)		2,913
Proceeds from ICP credit facilities		42,000			–
Proceeds from assessment financing		1,144			1,020
Net proceeds from notes		13,530			–
Payments for debt issuance costs		(924	)		–
Principal payments on borrowings		(54,927	)		(17,003	)
Payments on capital leases		(588	)		(3,151	)
Proceeds from exercise of warrants and options		1,202			–
Preferred stock dividends paid		(946	)		(949	)
Net cash used in financing activities		(5,398	)		(17,170	)
Net decrease in cash and cash equivalents		(11,667	)		(12,073	)
Cash and cash equivalents at beginning of period		68,590			52,712
Cash and cash equivalents at end of period	$	56,923		$	40,639
Supplemental Cash Flow Information:
Interest paid	$	8,291		$	7,256
Income tax refunds received	$	5,601		$	4,784
Noncash financing and investing activities:
Issuance of notes payable for acquisition of ICP	$	46,927		$	–
Reclass of warrant liability to equity upon warrant exercises	$	178		$	–

See accompanying notes to consolidated financial statements.

6

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)

1. ORGANIZATION AND BASIS OF PRESENTATION.

Organization and Business – The consolidated financial statements include, for all periods presented, the accounts of Pacific Ethanol, Inc., a Delaware corporation (“Pacific Ethanol”), and its direct and indirect subsidiaries (collectively, the “Company”), including its wholly-owned subsidiaries, Kinergy Marketing LLC, an Oregon limited liability company (“Kinergy”), Pacific Ag. Products, LLC, a California limited liability company (“PAP”), PE Op Co., a Delaware corporation (“PE Op Co.”) and eight of the Company’s ethanol production facilities. The Company’s acquisition of Illinois Corn Processing, LLC (“ICP”) was consummated on July 3, 2017, and as a result, the Company’s consolidated financial statements include the results of ICP commencing July 3, 2017 and all other periods presented exclude the results of ICP prior to that date. See Note 2 – Acquisition of ICP.

On December 15, 2016, the Company and Aurora Cooperative Elevator Company, a Nebraska cooperative corporation (“ACEC”), closed a transaction under a contribution agreement under which the Company contributed its Aurora, Nebraska ethanol facilities and ACEC contributed its Aurora grain elevator and related grain handling assets to Pacific Aurora, LLC (“Pacific Aurora”) in exchange for equity interests in Pacific Aurora. On December 15, 2016, concurrently with the closing under the contribution agreement, the Company sold a portion of its equity interest in Pacific Aurora to ACEC. As a result, as of December 15, 2016 and through September 30, 2017, the Company owned 73.93% of Pacific Aurora and ACEC owned 26.07% of Pacific Aurora. The Company consolidates 100% of the results of Pacific Aurora and records ACEC’s 26.07% equity interest as noncontrolling interests in the accompanying financial statements.

The Company is a leading producer and marketer of low-carbon renewable fuels and high-quality alcohol products in the United States. The Company owns and operates nine production facilities, four in the Western states of California, Oregon and Idaho, and five in the Midwestern states of Illinois and Nebraska. The Company’s four ethanol plants in the Western United States (together with their respective holding companies, the “Pacific Ethanol West Plants”) are located in close proximity to both feed and ethanol customers and thus enjoy unique advantages in efficiency, logistics and product pricing. These plants produce among the lowest-carbon ethanol produced in the United States due to low energy use in production.

The Company has production capacity of 605 million gallons per year, markets, on an annualized basis, nearly 1.0 billion gallons of ethanol, and produces, on an annualized basis, over 2.5 million tons of co-products such as wet and dry distillers grains, wet and dry corn gluten feed, condensed distillers solubles, corn gluten meal, corn germ, dried yeast and CO₂. The Company’s five ethanol plants in the Midwest (together with their respective holding companies, the “Pacific Ethanol Central Plants”) are located in the heart of the Corn Belt, benefit from low-cost and abundant feedstock production and allow for access to many additional domestic markets. In addition, the Company’s ability to load unit trains from these facilities in the Midwest, and barges from its Pekin, Illinois plants, allows for greater access to international markets.

Basis of Presentation–Interim Financial Statements – The accompanying unaudited consolidated financial statements and related notes have been prepared in accordance with accounting principles generally accepted in the United States for interim financial information and the instructions to Form 10-Q and Rule 10-01 of Regulation S-X. Results for interim periods should not be considered indicative of results for a full year. These interim consolidated financial statements should be read in conjunction with the consolidated financial statements and related notes contained in the Company’s Annual Report on Form 10-K for the year ended December 31, 2016. The accounting policies used in preparing these consolidated financial statements are the same as those described in Note 1 to the consolidated financial statements in the Company’s Annual Report on Form 10-K for the year ended December 31, 2016. In the opinion of management, all adjustments (consisting of normal recurring adjustments) considered necessary for a fair statement of the results for interim periods have been included. All significant intercompany accounts and transactions have been eliminated in consolidation.

Accounts Receivable and Allowance for Doubtful Accounts – Trade accounts receivable are presented at face value, net of the allowance for doubtful accounts. The Company sells ethanol to gasoline refining and distribution companies, sells distillers grains and other feed co-products to dairy operators and animal feedlots and sells corn oil to poultry and biodiesel customers generally without requiring collateral.

7

The Company maintains an allowance for doubtful accounts for balances that appear to have specific collection issues. The collection process is based on the age of the invoice and requires attempted contacts with the customer at specified intervals. If, after a specified number of days, the Company has been unsuccessful in its collection efforts, a bad debt allowance is recorded for the balance in question. Delinquent accounts receivable are charged against the allowance for doubtful accounts once uncollectibility has been determined. The factors considered in reaching this determination are the apparent financial condition of the customer and the Company’s success in contacting and negotiating with the customer. If the financial condition of the Company’s customers were to deteriorate, resulting in an impairment of ability to make payments, additional allowances may be required.

Of the accounts receivable balance, approximately $57,237,000 and $64,853,000 at September 30, 2017 and December 31, 2016, respectively, were used as collateral under Kinergy’s operating line of credit. The allowance for doubtful accounts was $18,000 and $331,000 as of September 30, 2017 and December 31, 2016, respectively. The Company recorded a bad debt expense of $2,000 and $39,000 for the three months ended September 30, 2017 and 2016, respectively. The Company recorded a bad debt expense of $4,000 and $325,000 for the nine months ended September 30, 2017 and 2016, respectively. The Company does not have any off-balance sheet credit exposure related to its customers.

Provision for Income Taxes – The Company recognized no tax benefit for the three and nine months ended September 30, 2017 due to the uncertainty of using its tax losses to offset future taxable income. The Company recognized a tax benefit of $0.2 million for the nine months ended September 30, 2016, as the Company has finalized certain of its tax returns. The Company applied a valuation allowance against the amount of deferred tax losses from the periods. To the extent the Company believes it can utilize these losses, it will adjust its provision (benefit) for income taxes accordingly in future periods.

Financial Instruments – The carrying values of cash and cash equivalents, accounts receivable, accounts payable, accrued liabilities and accrued PE Op Co. purchase are reasonable estimates of their fair values because of the short maturity of these items. The Company recorded its warrant liabilities at fair value. The Company believes the carrying value of its long-term debt approximates fair value because the interest rates on these instruments are variable, and are considered Level 2 fair value measurements.

Recent Accounting Pronouncements – In February 2016, the Financial Accounting Standards Board (“FASB”) issued new guidance on accounting for leases. Under the new guidance, lessees will be required to recognize the following for all leases (with the exception of short-term leases) at the commencement date: (1) a lease liability, which is a lessee’s obligation to make lease payments arising from a lease, measured on a discounted cash flow basis; and (2) a “right of use” asset, which is an asset that represents the lessee’s right to use the specified asset for the lease term. Under the new guidance, lessor accounting is largely unchanged, with some minor exceptions. Lessees will no longer be provided with a source of off-balance sheet financing for other than short-term leases. The standard is effective for public companies for annual reporting periods beginning after December 15, 2019, and for interim periods beginning after December 15, 2020. Early adoption is permitted. The Company has several operating leases that may be impacted by this guidance. The Company is currently evaluating the impact of the adoption of this accounting standard on its consolidated results of operations and financial condition.

In May 2014, the FASB issued new guidance (“ASC 606”) on the recognition of revenue. ASC 606 states that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The standard is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. In March and April 2016, the FASB issued further revenue recognition guidance amending principal vs. agent considerations regarding whether an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services.

The provisions of ASC 606 include a five-step process by which an entity will determine revenue recognition, depicting the transfer of goods or services to customers in amounts reflecting the payment to which an entity expects to be entitled in exchange for those goods or services. ASC 606 requires the Company to apply the following steps: (1) identify the contract with the customer; (2) identify the performance obligations in the contract; (3) determine the transaction price; (4) allocate the transaction price to the performance obligations in the contract; and (5) recognize revenue when, or as, the Company satisfies the performance obligation.

The Company will adopt ASC 606 on January 1, 2018. The Company is currently in the process of completing an evaluation of the new requirements, under ASC 606, on each of its major revenue types. The Company’s initial preliminary assessment indicates that ASC 606 will not materially change the way the Company accounts for its contracts with its customers, which will continue to be recognized at a point in time. The Company anticipates finalizing its assessment of the financial impact of ASC 606 during the fourth quarter of 2017 and anticipates adopting the new guidance using the modified retrospective transition method.

8

In April 2016, the FASB issued new guidance to reduce the complexity of certain aspects of accounting for employee share-based payment transactions. Prior to adoption of the standard, accruals of compensation costs were based on an estimated forfeiture rate. The new guidance allows an entity to make an entity-wide accounting policy election to either continue using an estimate of forfeitures or account for forfeitures only when they occur. The guidance is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. Effective January 1, 2017, the Company elected to discontinue the use of an estimated forfeiture rate and instead account for actual forfeitures as they occur. The transition guidance requires an adjustment to retained earnings for any cumulative effect. The impact to the Company upon adoption was determined to be immaterial.

Estimates and Assumptions – The preparation of the consolidated financial statements in conformity with U.S. generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates are required as part of determining the fair value of warrants, allowance for doubtful accounts, net realizable value of inventory, estimated lives of property and equipment, long-lived asset impairments, valuation allowances on deferred income taxes and the potential outcome of future tax consequences of events recognized in the Company’s financial statements or tax returns, and the valuation of assets acquired and liabilities assumed as a result of business combinations. Actual results and outcomes may materially differ from management’s estimates and assumptions.

2. ACQUISITION OF ICP.

On June 26, 2017, the Company, through its wholly-owned direct and indirect subsidiaries PE Central, and ICP Merger Sub, LLC, a Delaware limited liability company and a direct wholly-owned subsidiary of PE Central (“Merger Sub”), entered into an Agreement and Plan of Merger (the “Merger Agreement”) with ICP, Illinois Corn Processing Holdings Inc. (“ICPH”) and MGPI Processing, Inc. (together with ICPH, the “Sellers”) to acquire 100% of the equity interests of ICP. The acquisition of ICP under the Merger Agreement was closed on July 3, 2017. At the closing, Merger Sub merged with and into ICP (the “Merger”), and ICP continues as the surviving corporation of the Merger and as a wholly-owned direct subsidiary of PE Central and a wholly-owned indirect subsidiary of the Company.

Upon closing and under the terms of the Merger Agreement, Merger Sub (i) paid to the Sellers $30,000,000 in cash, and (ii) issued to the Sellers secured promissory notes in the aggregate principal amount of approximately $46,927,000 (the “Seller Notes”). The Seller Notes were secured by a first priority lien on the assets of ICP and a pledge of the membership interests of ICP.

ICP is a 90 million gallon per year fuel and industrial alcohol manufacturing, storage and distribution facility adjacent to the Pacific Ethanol Pekin facility and is located on the Illinois River. ICP produces fuel-grade ethanol, beverage and industrial-grade alcohol, dry distillers grain (DDG) and corn oil. The facility has direct access to end-markets via barge, rail, and truck, and expands Pacific Ethanol’s domestic and international distribution channels.

The Company has recognized the following allocation of the purchase price at fair values. The following fair value allocation for all assets and liabilities is provisional and incomplete as the Company is in the process of completing its valuation of the assets acquired and liabilities assumed, most significantly its valuation of property and equipment, sellers notes and any income tax impact. The fair value of property and equipment is based on the Company’s draft valuations, and represents its best estimates at the time of the filing of this report. The Company expects to conclude its valuations during the fourth quarter of 2017. Preliminarily, no intangible assets or liabilities have been estimated due to ICP’s contracts being materially close to market prices. A final valuation may include either an asset or liability associated with any material out-of-market contract positions. Based upon these assumptions, the preliminary purchase price consideration allocation is as follows (in thousands):

Cash and equivalents	$	1,079
Accounts receivable		11,636
Inventories		9,858
Other current assets		907
Total current assets		23,480
Property and equipment		60,497
Other assets		328
Total assets acquired	$	84,305
Accounts payable, trade	$	5,683
Other current liabilities		1,486
Total current liabilities		7,169
Other non-current liabilities		209
Total liabilities assumed	$	7,378
Net assets acquired	$	76,927
Estimated goodwill	$	–
Total purchase price	$	76,927

9

The contractual amount due on the accounts receivable acquired was $11.6 million, all of which is expected to be collectible. Any changes to the initial estimates of the fair value of the acquired assets and assumed liabilities will be recorded as adjustments to those assets and liabilities and residual amounts will be allocated to goodwill if the net assets acquired are less than the purchase price. If the net assets acquired exceed the purchase price, the residual amount will result in a bargain purchase gain.

The following table presents unaudited pro forma combined financial information assuming the acquisition occurred on January 1, 2016.

	Three Months Ended September 30,			Nine Months Ended September 30,
	2016			2017			2016
Revenues – pro forma	$	461,825		$	1,315,046		$	1,317,243
Net loss – pro forma	$	(3,302	)	$	(27,145	)	$	(10,110	)
Diluted net income (loss) per share – pro forma	$	(0.08	)	$	(0.64	)	$	(0.24	)
Diluted weighted-average shares – pro forma		42,226			42,358			42,156

For the three and nine months ended September 30, 2017, ICP contributed $38.2 million in net revenues and $1.4 million in pre-tax income. For the three and nine months ended September 30, 2017, the Company recorded approximately $0.3 million in costs associated with the ICP acquisition. These costs are reflected in selling, general and administrative expenses on the Company’s consolidated statements of operations.

3. SEGMENTS.

The Company reports its financial and operating performance in two segments: (1) ethanol production, which includes the production and sale of ethanol, specialty alcohols and co-products, with all of the Company’s production facilities aggregated, and (2) marketing and distribution, which includes marketing and merchant trading for Company-produced ethanol, specialty alcohols and co-products and third-party ethanol.

The following tables set forth certain financial data for the Company’s operating segments (in thousands):

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Net Sales
Ethanol Production:
Net sales to external customers	$	304,812		$	266,299		$	804,012		$	767,171
Intersegment net sales		639			306			1,138			829
Total ethanol production net sales	$	305,451		$	266,605		$	805,150		$	768,000
Marketing and distribution:
Net sales to external customers	$	140,630		$	151,507		$	432,972		$	415,868
Intersegment net sales		2,334			2,018			6,135			5,861
Total marketing and distribution net sales		142,964			153,525			439,107			421,729
Intersegment eliminations		(2,973	)		(2,324	)		(7,273	)		(6,690	)
Net sales as reported	$	445,442		$	417,806		$	1,236,984		$	1,183,039

Cost of goods sold:
Ethanol production	$	292,743		$	262,964		$	797,277		$	759,210
Marketing and distribution		142,303			153,406			437,110			412,225
Intersegment eliminations		(1,669	)		(4,928	)		(5,348	)		(13,533	)
Cost of goods sold as reported	$	433,377		$	411,442		$	1,229,039		$	1,157,902

10

Income (loss) before provision for income taxes:
Ethanol production	$	2,638		$	(2,903	)	$	(15,981	)	$	(19,171	)
Marketing and distribution		(757	)		(1,524	)		(2,043	)		4,654
Corporate activities		(2,422	)		909			(5,940	)		2,614
	$	(541	)	$	(3,518	)	$	(23,964	)	$	(11,903	)
Depreciation and amortization:
Ethanol production	$	9,841		$	8,631		$	27,703		$	25,839
Marketing and distribution		–			–			–			3
Corporate activities		238			226			783			684
	$	10,079		$	8,857		$	28,486		$	26,526
Interest expense:
Ethanol production	$	1,850		$	3,521		$	4,061		$	15,600
Marketing and distribution		342			353			952			1,043
Corporate activities		1,634			–			4,144			–
	$	3,826		$	3,874		$	9,157		$	16,643

The following table sets forth the Company’s total assets by operating segment (in thousands): 

	September 30, 2017		December 31, 2016
Total assets:
Ethanol production	$	596,928	$	542,688
Marketing and distribution		129,294		146,356
Corporate assets		4,428		19,194
	$	730,650	$	708,238

4. INVENTORIES.

Inventories consisted primarily of bulk ethanol, corn, co-products, Low-Carbon Fuel Standard (“LCFS”) credits and unleaded fuel, and are valued at the lower of cost and net realizable value, with cost determined on a first-in, first-out basis.

Inventory balances consisted of the following (in thousands):

	September 30, 2017		December 31, 2016
Finished goods	$	46,314	$	33,773
Work in progress		9,637		7,092
Raw materials		8,401		6,571
LCFS credits		5,892		10,926
Other		1,575		1,708
Total	$	71,819	$	60,070

5. DERIVATIVES.

The business and activities of the Company expose it to a variety of market risks, including risks related to changes in commodity prices. The Company monitors and manages these financial exposures as an integral part of its risk management program. This program recognizes the unpredictability of financial markets and seeks to reduce the potentially adverse effects that market volatility could have on operating results.

Commodity Risk – Cash Flow Hedges – The Company uses derivative instruments to protect cash flows from fluctuations caused by volatility in commodity prices for periods of up to twelve months to protect gross profit margins from potentially adverse effects of market and price volatility on ethanol sale and purchase commitments where the prices are set at a future date and/or if the contracts specify a floating or index-based price for ethanol. In addition, the Company hedges anticipated sales of ethanol to minimize its exposure to the potentially adverse effects of price volatility. These derivatives may be designated and documented as cash flow hedges and effectiveness is evaluated by assessing the probability of the anticipated transactions and regressing commodity futures prices against the Company’s purchase and sales prices. Ineffectiveness, which is defined as the degree to which the derivative does not offset the underlying exposure, is recognized immediately in cost of goods sold. For the three and nine months ended September 30, 2017 and 2016, the Company did not designate any of its derivatives as cash flow hedges.

11

Commodity Risk – Non-Designated Hedges – The Company uses derivative instruments to lock in prices for certain amounts of corn and ethanol by entering into exchange-traded forward contracts for those commodities. These derivatives are not designated for special hedge accounting treatment. The changes in fair value of these contracts are recorded on the balance sheet and recognized immediately in cost of goods sold. The Company recognized losses of $483,000 and gains of $859,000 as the changes in the fair values of these contracts for the three months ended September 30, 2017 and 2016, respectively. The Company recognized losses of $836,000 and gains of $1,669,000 as the changes in the fair values of these contracts for the nine months ended September 30, 2017 and 2016, respectively.

Non Designated Derivative Instruments – The classification and amounts of the Company’s derivatives not designated as hedging instruments are as follows (in thousands):

	As of September 30, 2017
	Assets			Liabilities
Type of Instrument	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity contracts	Derivative instruments	$	3,017	Derivative instruments	$	2,755

	As of December 30, 2016
	Assets			Liabilities
Type of Instrument	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity contracts	Derivative instruments	$	978	Derivative instruments	$	4,115

The classification and amounts of the Company’s recognized gains (losses) for its derivatives not designated as hedging instruments are as follows (in thousands):

		Realized Gains (Losses)
		Three Months Ended September 30,
Type of Instrument	Statements of Operations Location	2017			2016
Commodity contracts	Cost of goods sold	$	(1,576	)	$	2,242

		Unrealized Gains (Losses)
		Three Months Ended September 30,
Type of Instrument	Statements of Operations Location	2017		2016
Commodity contracts	Cost of goods sold	$	1,093	$	(1,383	)

		Realized Gains (Losses)
		Nine Months Ended September 30,
Type of Instrument	Statements of Operations Location	2017			2016
Commodity contracts	Cost of goods sold	$	(4,495	)	$	2,152

		Unrealized Gains (Losses)
		Nine Months Ended September 30,
Type of Instrument	Statements of Operations Location	2017		2016
Commodity contracts	Cost of goods sold	$	3,659	$	(483	)

12

6. DEBT.

Long-term borrowings are summarized as follows (in thousands):

	September 30, 2017			December 31, 2016
Kinergy line of credit	$	43,973		$	49,862
Pekin term loan		57,000			64,000
Pekin revolving loan		32,000			32,000
ICP term loan		24,000			–
ICP revolving loan		18,000			–
Pacific Aurora line of credit		–			1,000
Parent notes payable		68,948			55,000
		243,921			201,862
Less unamortized debt discount		(1,590	)		(1,626	)
Less unamortized debt financing costs		(2,027	)		(1,708	)
Less short-term portion		(20,000	)		(10,500	)
Long-term debt	$	220,304		$	188,028

Kinergy Operating Line of Credit – On August 2, 2017, Kinergy increased its revolving line of credit from $85 million to $100 million. As of September 30, 2017, Kinergy had additional borrowing availability under its credit facility of $22,410,000.

Changes to Pekin Credit Facilities — On August 7, 2017, PE Pekin amended its term and revolving credit facilities by agreeing to increase the interest rate under the facilities by 25 basis points to an annual rate equal to the 30-day LIBOR plus 4.00%. PE Pekin and its lender also agreed that PE Pekin is required to maintain working capital of not less than $17.5 million from August 31, 2017 through December 31, 2017 and working capital of not less than $20.0 million from January 1, 2018 and continuing at all times thereafter. In addition, the required Debt Service Coverage Ratio was reduced to 0.15 to 1.00 for the fiscal year ending December 31, 2017.

ICP Credit Facilities — On September 15, 2017, ICP, Compeer Financial, PCA (“Lender”), and CoBank, ACB (“Agent”) entered into a Credit Agreement (“ICP Credit Agreement”). Under the ICP Credit Agreement, the Lender agreed to extend to ICP a term loan in the amount of $24,000,000 and a revolving loan in an amount of up to $18,000,000.

Under the term loan, ICP is to use the proceeds of the loan to refinance the Seller Notes. ICP is to make amortizing principal payments in sixteen equal consecutive quarterly installments of $1,500,000 each until September 20, 2021, at which time the entire remaining balance is due and payable. Interest on the unpaid principal amount of the term loan accrues at a rate equal to 3.75% plus the one-month LIBOR index rate.

Under the revolving loan, ICP is to use the proceeds of the revolving term facility to refinance the Seller Notes and for ICP’s working capital needs. The revolving loan matures on September 1, 2022. The revolving loan gives ICP the right, in ICP’s sole discretion, to permanently reduce from time to time the revolving term commitment in increments of $500,000 by giving the Agent ten days prior written notice.

The revolving loan requires ICP to pay the Agent a nonrefundable commitment fee equal to 0.75% per annum multiplied by the average daily positive difference between the amounts of (i) the revolving term commitment, minus (ii) the aggregate principal amount of all loans outstanding under the revolving loan. Interest on the unpaid principal amount of the loan accrues, pursuant to ICP’s election of the LIBOR Index Option, at a rate equal to 3.75% plus the one-month LIBOR index rate.

Under the terms of the credit facilities, ICP is required to maintain working capital of not less than $8.0 million. In addition, ICP is required to maintain an annual debt coverage ratio of not less than 1.5 to 1.0 beginning for the year ending December 31, 2018.

Changes to Pacific Aurora Credit Facility — On September 1, 2017, Pacific Aurora and its lender agreed that Pacific Aurora is required to maintain working capital of not less than $18.0 million from September 30, 2017 through February 28, 2018 and working capital of not less than $20.0 million from March 1, 2018 and continuing at all times thereafter. In addition, the required Debt Service Coverage Ratio was reduced to 0.00 to 1.00 for the fiscal year ending December 31, 2017 and 1.50 to 1.00 for the fiscal year ending December 31, 2018.

13

Parent Notes Payable – On June 26, 2017, the Company entered into a Note Purchase Agreement (the “Note Purchase Agreement”) with five accredited investors (the “Investors”) and a related Consent of Holders and Amendment of Senior Secured Notes with the Investors and holders of the Company’s senior secured notes issued on December 15, 2016 (“Prior Senior Notes”). On June 30, 2017, under the terms of the Note Purchase Agreement, the Company sold $13,948,000 in aggregate principal amount of its senior secured notes (the “Senior Notes”) to the Investors in a private offering for aggregate gross proceeds of 97% of the principal amount of the Senior Notes sold. Upon issuance, the Company recorded $418,000 in unamortized debt discount.

Distribution Restrictions – At September 30, 2017, there were $305,660,000 of net assets of the Company’s subsidiaries that were not available to be transferred to Pacific Ethanol in the form of dividends, loans or advances due to restrictions contained in the credit facilities of the Company’s subsidiaries.

7. WARRANTS AND STOCK OPTIONS.

Warrant and Option Exercises – During the nine months ended September 30, 2017, certain holders exercised warrants and options and received an aggregate of 201,000 shares of the Company’s common stock upon payment of an aggregate of $1,201,000 in cash. There were no warrants or options exercised during the three months ended September 30, 2017 and the three and nine months ended September 30, 2016. As of September 30, 2017, there were no warrants outstanding for which we account using fair value methodologies; accordingly, no fair value adjustments will be made in future periods relating to currently outstanding warrants.

8. COMMITMENTS AND CONTINGENCIES.

Sales Commitments – At September 30, 2017, the Company had entered into sales contracts with its major customers to sell certain quantities of ethanol and co-products. The Company had open ethanol indexed-price contracts for 224,150,000 gallons of ethanol as of September 30, 2017 and open fixed-price ethanol sales contracts totaling $53,672,000 as of September 30, 2017. The Company had open fixed-price co-product sales contracts totaling $30,375,000 and open indexed-price co-product sales contracts for 16,000 tons as of September 30, 2017. These sales contracts are scheduled to be completed through 2018.

Purchase Commitments – At September 30, 2017, the Company had indexed-price purchase contracts to purchase 20,050,000 gallons of ethanol and fixed-price purchase contracts to purchase $9,476,000 of ethanol from its suppliers. The Company had $11,000,000 of fixed-price corn purchase contracts and basis contracts with its suppliers as of September 30, 2017. These purchase commitments are scheduled to be satisfied through 2018.

Litigation – General – The Company is subject to various claims and contingencies in the ordinary course of its business, including those related to litigation, business transactions, employee-related matters, and others. When the Company is aware of a claim or potential claim, it assesses the likelihood of any loss or exposure. If it is probable that a loss will result and the amount of the loss can be reasonably estimated, the Company will record a liability for the loss. If the loss is not probable or the amount of the loss cannot be reasonably estimated, the Company discloses the claim if the likelihood of a potential loss is reasonably possible and the amount involved could be material. While there can be no assurances, the Company does not expect that any of its pending legal proceedings will have a material impact on the Company’s financial condition or results of operations.

The Company assumed certain legal matters which were ongoing at July 1, 2015, the date of the Company’s acquisition of Aventine Renewable Energy Holdings, Inc (“PE Central”). Among them were lawsuits between Aventine Renewable Energy, Inc. (now known as Pacific Ethanol Pekin, LLC, or “PE Pekin”) and Glacial Lakes Energy, Aberdeen Energy and Redfield Energy, together, the “Defendants,” in which PE Pekin sought damages for breach of termination agreements that wound down ethanol marketing arrangements between PE Pekin and each of the Defendants. In February and March 2017, the Company and the Defendants entered into settlement agreements and the Defendants paid in cash to the Company $3.9 million in final resolution of these matters. The Company did not assign any value to the claims against the Defendants in its accounting for the Aventine acquisition as of July 1, 2015. The Company recorded a gain, net of legal fees, of $3.6 million upon receipt of the cash settlement and recognized the gain in selling, general and administrative expenses in the consolidated statements of operations for the nine months ended September 30, 2017.

9. PENSION AND RETIREMENT BENEFIT PLANS.

The Company sponsors a defined benefit pension plan (the “Retirement Plan”) and a health care and life insurance plan (the “Postretirement Plan”). The Company assumed the Retirement Plan and the Postretirement Plan as part of its acquisition of PE Central on July 1, 2015.

The Retirement Plan is noncontributory, and covers only “grandfathered” unionized employees at the Company’s Pekin, Illinois facility who fulfill minimum age and service requirements. Benefits are based on a prescribed formula based upon the employee’s years of service. The Retirement Plan, which is part of a collective bargaining agreement, covers only union employees hired prior to November 1, 2010.

14

The Company uses a December 31 measurement date for its Retirement Plan. The Company’s funding policy is to make the minimum annual contributions that are required by applicable regulations. As of December 31, 2016, the Retirement Plan’s accumulated projected benefit obligation was $18.5 million, with a fair value of plan assets of $12.4 million. The underfunded amount of $6.1 million is recorded on the Company’s consolidated balance sheet in other noncurrent liabilities.

The Company’s net periodic Retirement Plan costs are as follows (in thousands):

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Interest cost	$	98		$	172		$	293		$	516
Service cost		188			56			563			168
Expected return on plan assets		(169	)		(199	)		(506	)		(597	)
Net periodic expense	$	117		$	29		$	350		$	87

The Postretirement Plan provides postretirement medical benefits and life insurance to certain “grandfathered” unionized employees. Employees hired after December 31, 2000 are not eligible to participate in the Postretirement Plan. The Postretirement Plan is contributory, with contributions required at the same rate as active employees. Benefit eligibility under the plan reduces at age 65 from a defined benefit to a defined dollar cap based upon years of service. As of December 31, 2016, the Postretirement Plan’s accumulated projected benefit obligation was $5.4 million and is recorded on the Company’s consolidated balance sheet in other noncurrent liabilities. The Company’s funding policy is to make the minimum annual contributions that are required by applicable regulations.

The Company’s net periodic Postretirement Plan costs are as follows (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
Interest cost	$	21	$	35	$	63	$	105
Service cost		50		12		150		36
Amortization of (gain) loss		33		–		99		–
Net periodic expense	$	104	$	47	$	312	$	141

10. FAIR VALUE MEASUREMENTS.

The fair value hierarchy prioritizes the inputs used in valuation techniques into three levels, as follows:

· Level 1 – Observable inputs – unadjusted quoted prices in active markets for identical assets and liabilities;

· Level 2 – Observable inputs other than quoted prices included in Level 1 that are observable for the asset or liability through corroboration with market data; and

· Level 3 – Unobservable inputs – includes amounts derived from valuation models where one or more significant inputs are unobservable. For fair value measurements using significant unobservable inputs, a description of the inputs and the information used to develop the inputs is required along with a reconciliation of Level 3 values from the prior reporting period.

15

Warrants – The Company’s warrants were valued using a Monte Carlo Binomial Lattice-Based valuation methodology, adjusted for marketability restrictions. The Company recorded its warrants issued in 2012 at fair value and designated them as Level 3 on their issuance dates.

Significant assumptions used and related fair values for the warrants as of December 31, 2016 were as follows:

Original Issuance	Exercise Price	Volatility	Risk Free Interest Rate	Term (years)	Market Discount	Warrants Outstanding	Fair Value
07/3/2012	$6.09	40.9%	0.62%	0.50	11.3%	211,000	$651,000

Other Derivative Instruments – The Company’s other derivative instruments consist of commodity positions. The fair values of the commodity positions are based on quoted prices on the commodity exchanges and are designated as Level 1 inputs.

The following table summarizes recurring fair value measurements by level at September 30, 2017 (in thousands):

	Fair
	Value			Level 1			Level 2		Level 3
Assets:
Derivative instruments	$	3,017		$	3,017		$	–	$	–
	$	3,017		$	3,017		$	–	$	–
Liabilities:
Warrants	$	–		$	–		$	–	$	–
Derivative instruments		(2,755	)		(2,755	)		–		–
	$	(2,755	)	$	(2,755	)	$	–	$	–

The changes in the Company’s fair value of its Level 3 inputs with respect to its warrants were as follows (in thousands):

Balance, December 31, 2016	$	651
Exercised warrants		(178	)
Adjustments to fair value for the period		(473	)
Balance, September 30, 2017	$	–

11. EARNINGS PER SHARE.

The following tables compute basic and diluted earnings per share (in thousands, except per share data):

	Three Months Ended September 30, 2017
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(202	)
Less: Preferred stock dividends		(319	)
Basic and diluted loss per share:
Loss available to common stockholders	$	(521	)		42,475	$	(0.01	)

	Three Months Ended September 30, 2016
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(3,518	)
Less: Preferred stock dividends		(319	)
Basic and diluted loss per share:
Loss available to common stockholders	$	(3,837	)		42,226	$	(0.09	)

16

	Nine Months Ended September 30, 2017
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(21,679	)
Less: Preferred stock dividends		(946	)
Basic and diluted loss per share:
Loss available to common stockholders	$	(22,625	)		42,358	$	(0.53	)

	Nine Months Ended September 30, 2016
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(11,658	)
Less: Preferred stock dividends		(949	)
Basic and diluted loss per share:
Loss available to common stockholders	$	(12,607	)		42,156	$	(0.30	)

There were an aggregate of 688,000 and 737,000 potentially dilutive weighted-average shares from the Company’s warrants and shares of Series B Cumulative Convertible Preferred Stock outstanding for the three and nine months ended September 30, 2017, respectively. These convertible securities were not considered in calculating diluted net loss per share for the three and nine months ended September 30, 2017, as their effect would have been anti-dilutive.

17

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

The following discussion and analysis should be read in conjunction with our consolidated financial statements and notes to consolidated financial statements included elsewhere in this report. This report and our consolidated financial statements and notes to consolidated financial statements contain forward-looking statements, which generally include the plans and objectives of management for future operations, including plans and objectives relating to our future economic performance and our current beliefs regarding revenues we might generate and profits we might earn if we are successful in implementing our business and growth strategies. The forward-looking statements and associated risks may include, relate to or be qualified by other important factors, including:

· fluctuations in the market price of ethanol and its co-products;

· fluctuations in the costs of key production input commodities such as corn and natural gas;

· the projected growth or contraction in the ethanol and co-product markets in which we operate;

· our strategies for expanding, maintaining or contracting our presence in these markets;

· anticipated trends in our financial condition and results of operations; and

· our ability to distinguish ourselves from our current and future competitors.

You are cautioned not to place undue reliance on any forward-looking statements, which speak only as of the date of this report, or in the case of a document incorporated by reference, as of the date of that document. We do not undertake to update, revise or correct any forward-looking statements, except as required by law.

Any of the factors described immediately above, or referenced from time to time in our filings with the Securities and Exchange Commission or in the “Risk Factors” section below could cause our financial results, including our net income or loss or growth in net income or loss to differ materially from prior results, which in turn could, among other things, cause the price of our common stock to fluctuate substantially.

Recent Development

On July 3, 2017, we completed our acquisition of Illinois Corn Processing LLC, or ICP, under the terms of an Agreement and Plan of Merger dated as of June 26, 2017 by and among Pacific Ethanol Central, LLC, ICP Merger Sub, LLC, Illinois Corn Processing Holdings Inc., MGPI Processing, Inc., and ICP. ICP is a 90 million gallon per year fuel and industrial alcohol manufacturing, storage and distribution facility located on the Illinois River adjacent to our facilities in Pekin, Illinois. ICP produces fuel-grade ethanol, beverage and industrial-grade alcohol, dry distillers grain with solubles, or DDGS, and corn oil. ICP’s facility has direct access to end-markets via barge, rail and truck. We acquired ICP for $76.9 million, of which $30.0 million was paid in cash and $46.9 million was paid through the issuance of non-amortizing secured promissory notes, which have been subsequently repaid.

Our acquisition of ICP adds 90 million gallons per year of production capacity, diversifies fuel ethanol production with high-value beverage and industrial grade alcohol, and expands Pacific Ethanol’s domestic and international distribution channels. Two-thirds of ICP’s production is currently dedicated to producing high-quality, premium-priced alcohol products for the beverage and industrial markets. The consolidation of the ICP facility with our two Pekin, Illinois plants is expected to integrate the Pekin site into a unique combination of technologies and products with a combined operating capacity of 250 million gallons per year. We expect the acquisition will yield approximately $4.5 million in annual cost savings over the twelve month period following the acquisition, including economies of scale in purchasing power, managing grain supply and transportation costs for DDG and ethanol. The acquisition is immediately accretive to earnings. We believe the acquisition will have a continued positive impact on our earnings as ICP’s beverage and industrial grade alcohol products are priced at a premium to fuel ethanol.

18

Overview

We are a leading producer and marketer of low-carbon renewable fuels in the United States.

We own and operate nine strategically-located production facilities. Four of our plants are in the Western states of California, Oregon and Idaho, and five of our plants are located in the Midwestern states of Illinois and Nebraska. We are the sixth largest producer of ethanol in the United States based on annualized volumes. Our plants have a combined production capacity of 605 million gallons per year. We market all the ethanol, specialty alcohols and co-products produced at our plants as well as ethanol produced by third parties. On an annualized basis, we market nearly 1.0 billion gallons of ethanol and over 2.5 million tons of ethanol co-products on a dry matter basis. Our business consists of two operating segments: a production segment and a marketing segment.

Our mission is to advance our position and significantly increase our market share as a leading producer and marketer of low-carbon renewable fuels in the United States. We intend to accomplish this goal in part by expanding our ethanol production capacity and distribution infrastructure, accretive acquisitions, lowering the carbon intensity of our ethanol, extending our marketing business into new regional and international markets, and implementing new technologies to promote higher production yields and greater efficiencies.

Production Segment

We produce ethanol, specialty alcohols and co-products at our production facilities described below. Our plants located on the West Coast are near their respective fuel and feed customers, offering significant timing, transportation cost and logistical advantages. Our plants located in the Midwest are in the heart of the Corn Belt, benefit from low-cost and abundant feedstock production and allow for access to many additional domestic markets. In addition, our ability to load unit trains from our plants located in the Midwest, and barges from our Pekin, Illinois plants, allows for greater access to international markets.

We wholly-own all of our plants located on the West Coast and the three plants in Pekin, Illinois. We own approximately 74% of the two plants in Aurora, Nebraska as well as the grain elevator adjacent to those properties and related grain handling assets, including the outer rail loop, and the real property on which they are located, through Pacific Aurora, LLC, or Pacific Aurora, an entity owned approximately 26% by Aurora Cooperative Elevator Company.

Facility Name	Facility Location	Estimated Annual Capacity (gallons)
Magic Valley	Burley, ID	60,000,000
Columbia	Boardman, OR	40,000,000
Stockton	Stockton, CA	60,000,000
Madera	Madera, CA	40,000,000
Aurora West	Aurora, NE	110,000,000
Aurora East	Aurora, NE	45,000,000
Pekin Wet	Pekin, IL	100,000,000
Pekin Dry	Pekin, IL	60,000,000
Pekin ICP	Pekin, IL	90,000,000

We produce ethanol co-products at our production facilities such as wet distillers grains, or WDG, DDGS, wet and dry corn gluten feed, condensed distillers solubles, corn gluten meal, corn germ, corn oil, dried yeast and CO₂.

Marketing Segment

We market ethanol, specialty alcohols and co-products produced by our facilities and market ethanol produced by third parties. We have extensive customer relationships throughout the Western and Midwestern United States. Our ethanol customers are integrated oil companies and gasoline marketers who blend ethanol into gasoline. Our customers depend on us to provide a reliable supply of ethanol, and manage the logistics and timing of delivery with very little effort on their part. Our customers collectively require ethanol volumes in excess of the supplies we produce at our production facilities. We secure additional ethanol supplies from third-party plants in California and other third-party suppliers in the Midwest where a majority of ethanol producers are located. We arrange for transportation, storage and delivery of ethanol purchased by our customers through our agreements with third-party service providers in the Western United States as well as in the Midwest from a variety of sources.

19

We market our distillers grains and other feed co-products to dairies and feedlots, in many cases located near our ethanol plants. These customers use our feed co-products for livestock as a substitute for corn and other sources of starch and protein. We sell our corn oil to poultry and biodiesel customers. We do not market co-products from other ethanol producers.

See “Note 3 – Segments” to our Notes to Consolidated Financial Statements included elsewhere in this report for financial information about our business segments.

Outlook

Our results for the third quarter reflect an improved margin environment and the benefits of our acquisition of ICP. Despite a slow start, margins improved throughout the quarter with September producing the best financial results driven by higher ethanol sales prices and lower corn costs. Our results also reflect increased production gallons sold in the third quarter predominately from increased volumes from our recently acquired ICP facility.

Thus far in the fourth quarter we are off to a similarly slow start with overall lower production margins compared to the third quarter due to elevated production volumes and high industry-wide ethanol inventories. However, we expect ethanol demand to remain strong and continue to grow given continued strong gasoline demand and as domestic markets blend at ethanol levels above 10% and international markets grow to meet carbon targets and the higher demand for octane. The United States remains the lowest-cost source of ethanol for export and we continue to expect record ethanol export levels for 2017 and additional export growth in 2018. Ethanol is the lowest-cost source of octane in the world and, at current prices, ethanol is the lowest-cost source of liquid transportation fuel. Although we are cautious on the fourth quarter, we believe that the above factors will support an improved ethanol supply and demand balance in 2018.

On the regulatory front, the Environmental Protection Agency, or EPA, recently renewed its commitment to the renewable fuels program. In a letter to several U.S. Senators confirming his support for the Renewable Fuel Standard, or RFS, EPA chief Scott Pruitt stated that preliminary analysis suggests setting final Renewable Volume Obligation, or RVO, levels for 2018 at or above the proposed levels by the statutory deadline of November 30, 2017; that the EPA would soon finalize a decision to deny the request to change the point of obligation for Renewable Identification Numbers, or RINs; that the EPA will not pursue regulations amending the RFS to allow ethanol exports to generate RINs; and that the EPA is exploring its authority to remove artificial barriers to the year-round use of E15 fuel. We are pleased and encouraged by the EPA’s message and optimistic that the final RVO for 2018 will demonstrate the EPA’s commitment to growing the renewable fuels market.

Our 3.5 megawatt cogeneration system at our Stockton plant is on track to reach full capacity in the coming weeks. The system will convert process waste gas and natural gas into electricity and steam, reducing energy costs by up to $4.0 million per year and lowering air emissions.

We implemented an industrial scale membrane system at our Madera facility that separates water from ethanol during the plant’s dehydration process. The system is operating well and we expect a positive impact on energy savings, operating performance and our carbon intensity score. We are realizing energy savings of a 5% reduction in natural gas costs at the plant. Overall, we estimate the operating efficiencies, energy savings and carbon premium combined will total approximately $1.0 million annually at current market rates. The membrane system also improves operations during hot weather, yielding greater output, and it contributes to lowering our carbon intensity score. We have submitted for a new Low-Carbon Fuel Standard pathway with the California Air Resources Board and we continue to evaluate installation of membrane systems at our other plants.

We continue to produce cellulosic ethanol at our Stockton plant and we are on track to begin commercial production of cellulosic ethanol at our Madera plant this quarter. We have filed for approval from the EPA to produce D3 RINs at our Madera and Magic Valley plants. We expect EPA approval to produce D3 RINs at both facilities by early 2018, at which point three of our plants will be producing cellulosic ethanol from corn fiber. Although there are some risks around the market for advanced biofuels and the EPA is reluctant to enhance the statutory targets through regulation, we believe cellulosic ethanol from corn fiber will continue to spread throughout our production platform and the industry as a whole.

Also at our Madera facility, we remain on schedule to begin full-scale operation of our 5 megawatt solar photovoltaic power system in early 2018. We expect the system to reduce our utility costs by over $1.0 million annually and lower our carbon score.

20

Our integration of ICP is progressing very well and we anticipate annualized savings of $4.5 million over the next nine months, predominately from reduced operating and logistical costs as well as savings due to efficiencies in selling, general and administrative expense items. Our integration of personnel, and information technology and accounting services is effectively complete. We have begun internalizing logistical and storage services which we expect will accelerate and result in material benefits to our financial results in the coming quarters.

Our initial budget for capital projects in 2017 totaled $46.0 million, including $16.0 million in previously announced projects such as the completion of our Stockton cogeneration system, production of cellulosic ethanol at our Madera facility and our solar project. For the third quarter, we incurred $6.1 million in capital expenditures, bringing our nine-month total to $12.3 million. We expect that full-year capital expenditures will be less than $20.0 million. We intend to use the balance of budgeted uncommitted capital expenditure funds for investment opportunities in projects that produce the highest near-term return. Our capital expenditure budget does not include potential capital improvement projects at our ICP facilities. We expect to provide information regarding our capital expenditure projects for these facilities in the coming months.

We plan to continue to leverage our diverse base of production and marketing assets to advance our position and significantly increase market share as a leading producer and marketer of low-carbon renewable fuels and high-quality alcohol products in the United States. We also intend to continue to evaluate and invest in plant improvement and other initiatives to increase production and operating efficiencies, diversify products and revenues, improve our carbon scores and improve our plant profitability.

Critical Accounting Policies

The preparation of our financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America, requires us to make judgments and estimates that may have a significant impact upon the portrayal of our financial condition and results of operations. We believe that of our significant accounting policies, the following require estimates and assumptions that require complex, subjective judgments by management that can materially impact the portrayal of our financial condition and results of operations: revenue recognition; warrants at fair value; impairment of long-lived assets; valuation of allowance for deferred taxes, derivative instruments, accounting for business combinations and allowance for doubtful accounts. These significant accounting principles are more fully described in “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Policies” in our Annual Report on Form 10-K for the year ended December 31, 2016.

Results of Operations

The following selected financial information should be read in conjunction with our consolidated financial statements and notes to our consolidated financial statements included elsewhere in this report, and the other sections of “Management’s Discussion and Analysis of Financial Condition and Results of Operations” contained in this report.

Certain performance metrics that we believe are important indicators of our results of operations include:

	Three Months Ended September 30,				Percentage		Nine Months Ended September 30,				Percentage
	2017		2016		Variance		2017		2016		Variance
Production gallons sold (in millions)		141.8		125.5		13.0%		374.0		360.9	3.6%
Third party gallons sold (in millions)		108.2		118.2		(8.5)%		335.2		322.6	3.9%
Total gallons sold (in millions)		250.0		243.7		2.6%		709.2		683.5	3.8%
Production capacity utilization		93%		96%		(3.1)%		91%		92%	(1.1)%
Average ethanol sales price per gallon	$	1.69	$	1.62		4.3%	$	1.66	$	1.63	1.8%
Corn cost per bushel – CBOT equivalent	$	3.69	$	3.58		3.1%	$	3.67	$	3.70	(0.8)%
Average basis (1)	$	0.11	$	0.25		(56.0)%	$	0.21	$	0.27	(22.2)%
Delivered cost of corn	$	3.80	$	3.83		(0.8)%	$	3.88	$	3.97	(2.3)%
Total co-product tons sold (in thousands)		803.4		702.1		14.4%		2,223.2		2,050.3	8.4%
Co-product revenues as % of delivered cost of corn(2)		34.0%		35.7%		(4.8)%		34.2%		35.3%	(3.1)%
Average CBOT ethanol price per gallon	$	1.55	$	1.49		4.0%	$	1.54	$	1.49	3.4%
Average CBOT corn price per bushel	$	3.59	$	3.31		8.5%	$	3.64	$	3.77	3.4%

______________

(1) Corn basis represents the difference between the immediate cash price of delivered corn and the future price of corn for Chicago delivery.

(2) Co-product revenues as a percentage of delivered cost of corn shows our yield based on sales of co-products, including WDG and corn oil, generated from ethanol we produced.

21

Net Sales, Cost of Goods Sold and Gross Profit

The following table presents our net sales, cost of goods sold and gross profit in dollars and gross profit as a percentage of net sales (in thousands, except percentages):

	Three Months Ended September 30,				Variance in				Nine Months Ended September 30,				Variance in
	2017		2016		Dollars		Percent		2017		2016		Dollars			Percent
Net sales	$	445,442	$	417,806	$	27,636		6.6%	$	1,236,984	$	1,183,039	$	53,945			4.6%
Cost of goods sold		433,377		411,442		21,935		5.3%		1,229,039		1,157,902		71,137			6.1%
Gross profit	$	12,065	$	6,364	$	5,701		89.6%	$	7,945	$	25,137	$	(17,192	)		(68.4)%
Percentage of net sales		2.7%		1.5%						0.6%		2.1%

Net Sales

The increase in our net sales for the three and nine months ended September 30, 2017 as compared to the same periods in 2016 was primarily due to an increase in our average sales price per gallon and an increase in our production gallons sold, predominately from increased volumes attributed to our recently acquired ICP facility.

Three Months Ended September 30, 2017

On a consolidated basis, our average sales price per gallon increased 4.3% to $1.69 for the three months ended September 30, 2017 compared to our average sales price per gallon of $1.62 for the same period in 2016. The average Chicago Board of Trade, or CBOT, ethanol price per gallon, increased 4.0% to $1.55 for the three months ended September 30, 2017 as compared to the average CBOT ethanol price per gallon of $1.49 for the same period in 2016.

Production Segment

Net sales of ethanol from our production segment increased by $33.3 million, or 17%, to $234.5 million for the three months ended September 30, 2017 as compared to $201.2 million for the same period in 2016. Our total volume of production ethanol gallons sold increased by 16.3 million gallons, or 13%, to 141.8 million gallons for the three months ended September 30, 2017 as compared to 125.5 million gallons for the same period in 2016. Our production segment’s average sales price per gallon increased 3.1% to $1.65 for the three months ended September 30, 2017 compared to our production segment’s average sales price per gallon of $1.60 for the same period in 2016. At our average sales price per gallon of $1.65 for the three months ended September 30, 2017, we realized additional net sales of $27.0 million from our production segment from the 16.3 million additional gallons of produced ethanol sold in the three months ended September 30, 2017 as compared to the same period in 2016. The increase of $0.05 in our average sales price per gallon for the three months ended September 30, 2017 as compared to the same period in 2016 improved our net sales of ethanol from our production segment by $6.3 million.

Net sales of co-products increased $5.3 million, or 8%, to $70.4 million for the three months ended September 30, 2017 as compared to $65.1 million for the same period in 2016. Our total volume of co-products sold increased by 101.3 thousand tons, or 14%, to 803.4 thousand tons for three months ended September 30, 2017 from 702.1 thousand tons for the same period in 2016. At our average sales price per ton of $87.57 for the three months ended September 30, 2017, we generated $8.9 million in additional net sales from the 101.3 thousand tons of additional co-products sold in the three months ended September 30, 2017 as compared to the same period in 2016. The decrease of $5.15, or 6%, in our average sales price per ton for the three months ended September 30, 2017 as compared to the same period in 2016 reduced net sales of co-products by $3.6 million.

22

Marketing Segment

Net sales of ethanol from our marketing segment decreased by $10.9 million, or 7%, to $140.6 million for the three months ended September 30, 2017 as compared to $151.5 million for the same period in 2016. Our total volume of ethanol gallons sold by our marketing segment increased by 6.3 million gallons, or 3%, to 250.0 million gallons for the three months ended September 30, 2017 as compared to 243.7 million gallons for the same period in 2016. Our additional production gallons sold accounted for 16.3 million gallons of this increase, partially offset by a reduction in our third-party gallons sold of 10.0 million gallons.

The increase in production gallons sold by our marketing segment resulted in an increase of $0.1 million in net sales generated by our marketing segment, which were eliminated upon consolidation.

Our marketing segment’s average sales price per gallon increased $0.05, or 3%, to $1.70 for the three months ended September 30, 2017 as compared to $1.65 for the same period in 2016. At our average sales price per gallon of $1.70 for the three months ended September 30, 2017, we realized a reduction of $17.0 million in net sales from our marketing segment from the 10.0 million gallons in lower third-party ethanol gallons sold in the three months ended September 30, 2017 as compared to the same period in 2016. The increase of $0.05 in our average sales price per gallon for the three months ended September 30, 2017 as compared to the same period in 2016 increased our net sales of ethanol from our marketing segment by $6.1 million.

Nine Months Ended September 30, 2017

On a consolidated basis, our average sales price per gallon increased 1.8% to $1.66 for the nine months ended September 30, 2017 compared to our average sales price per gallon of $1.63 for the same period in 2016. The average CBOT ethanol price per gallon increased 3.4% to $1.54 for the nine months ended September 30, 2017 compared to an average CBOT ethanol price per gallon of $1.49 for the same period in 2016.

Production Segment

Net sales of ethanol from our production segment increased by $38.7 million, or 7%, to $613.6 million for the nine months ended September 30, 2017 as compared to $574.9 million for the same period in 2016. Our total volume of production ethanol gallons sold increased by 13.1 million gallons, or 4%, to 374.0 million gallons for the nine months ended September 30, 2017 as compared to 360.9 million gallons for the same period in 2016. Our production segment’s average sales price per gallon increased 3% to $1.64 for the nine months ended September 30, 2017 compared to our production segment’s average sales price per gallon of $1.59 for the same period in 2016. At our average sales price per gallon of $1.64 for the nine months ended September 30, 2017, we generated $21.5 million in additional net sales from our production segment from the 13.1 million additional gallons of produced ethanol sold in the nine months ended September 30, 2017 as compared to the same period in 2016. The increase of $0.05 in our average sales price per gallon for the nine months ended September 30, 2017 as compared to the same period in 2016 increased our net sales of ethanol from our production segment by $17.2 million.

Net sales of co-products decreased $1.8 million, or 1%, to $190.4 million for the nine months ended September 30, 2017 as compared to $192.2 million for the same period in 2016. Our total volume of co-products sold increased by 172.9 thousand tons, or 8%, to 2,223.2 thousand tons for the nine months ended September 30, 2017 from 2,050.3 thousand tons for the same period in 2016, however, our average sales price per ton declined. At our average sales price per ton of $85.66 for the nine months ended September 30, 2017, we generated $14.8 million in additional net sales from the 172.9 thousand additional tons of co-products sold in the nine months ended September 30, 2017 as compared to the same period in 2016. The decrease of $8.11, or 9%, in our average sales price per ton for the nine months ended September 30, 2017 as compared to the same period in 2016 decreased net sales of co-products by $16.6 million.

Marketing Segment

Net sales of ethanol from our marketing segment increased by $17.1 million, or 4%, to $433.0 million for the nine months ended September 30, 2017 as compared to $415.9 million for the same period in 2016. Our total volume of ethanol gallons sold by our marketing segment increased by 25.6 million gallons, or 4%, to 709.2 million gallons for the nine months ended September 30, 2017 as compared to 683.6 million gallons for the same period in 2016. Our additional production gallons sold accounted for 13.1 million gallons of this increase and our additional third-party gallons sold accounted for 12.5 million gallons of this increase.

23

Our marketing segment’s average sales price per gallon decreased $0.01 to $1.67 for the nine months ended September 30, 2017 compared to $1.68 for the same period in 2016. At our average sales price per gallon of $1.67 for the nine months ended September 30, 2017, we generated $20.9 million in additional net sales from our marketing segment from the 12.5 million gallons in additional third-party ethanol sold in the nine months ended September 30, 2017 as compared to the same period in 2016. However, the decline of $0.01 in our average sales price per gallon for the nine months ended September 30, 2017 as compared to the same period in 2016 reduced our net sales from third party ethanol sold by our marketing segment by $3.8 million.

Cost of Goods Sold and Gross Profit

Our consolidated gross profit increased primarily due to higher commodity margins in the three and nine months ended September 30, 2017 compared to the same periods in 2016.

Three Months Ended September 30, 2017

Our consolidated gross profit improved by $5.7 million for the three months ended September 30, 2017 to $12.1 million as compared to $6.4 million for the same period in 2016, representing a gross margin of 2.7% for the three months ended September 30, 2017 as compared to 1.5% for the same period in 2016.

Production Segment

Our production segment improved our consolidated gross profit by $5.4 million for the three months ended September 30, 2017 as compared to the same period in 2016, primarily due to higher production volumes and higher production margins for the three months ended September 30, 2017 as compared to the same period in 2016.

Marketing Segment

Our marketing segment improved our consolidated gross profit by $0.3 million for the three months ended September 30, 2017 as compared to the same period in 2016, primarily due to higher gross profit attributable to our marketing segment’s higher average sales price per gallon for the three months ended September 30, 2017 as compared to the same period in 2016.

Nine Months Ended September 30, 2017

Our consolidated gross profit declined by $17.2 million to a gross profit of $7.9 million for the nine months ended September 30, 2017 as compared to $25.1 million for the same period in 2016, representing a gross margin of 0.6% for the nine months ended September 30, 2017 as compared to a gross margin of 2.1% for the same period in 2016.

Production Segment

Our production segment reduced our consolidated gross profit by $10.0 million for the nine months ended September 30, 2017 as compared to the same period in 2016, primarily as a result of lower gross profit attributed to lower production margins in the nine months ended September 30, 2017 as compared to the same period in 2016.

Marketing Segment

Our marketing segment decreased our consolidated gross profit by $7.2 million for the nine months ended September 30, 2017 as compared to the same period in 2016, primarily as a result of lower gross profit attributed to lower marketing margins in the nine months ended September 30, 2017 as compared to the same period in 2016.

24

Selling, General and Administrative Expenses

The following table presents our selling, general and administrative, or SG&A, expenses in dollars and as a percentage of net sales (in thousands, except percentages):

	Three Months Ended September 30,				Variance in				Nine Months Ended September 30,				Variance in
	2017		2016		Dollars		Percent		2017		2016		Dollars		Percent
Selling, general and administrative expenses	$	8,720	$	5,971	$	2,749		46.0%	$	22,932	$	20,436	$	2,496		12.2%
Percentage of net sales		2.0%		1.4%						1.9%		1.7%

Our SG&A expenses increased $2.7 million to $8.7 million for the three months ended September 30, 2017 as compared to $6.0 million for the same period in 2016. The increase in SG&A expenses is primarily due to higher employee benefits, non-cash compensation and professional expenses associated with our ICP acquisition. We anticipate SG&A expenses of approximately $8.0 million for the fourth quarter.

Our SG&A expenses increased $2.5 million to $22.9 million for the nine months ended September 30, 2017 as compared to $20.4 million for the same period in 2016. The increase in SG&A expenses is primarily due to higher employee benefits, non-cash compensation and professional expenses associated with our ICP acquisition, partially offset by $3.6 million in gains associated with legal matters resolved in the first quarter.

Interest Expense, net

The following table presents our interest expense, net in dollars and as a percentage of net sales (in thousands, except percentages):

	Three Months Ended September 30,				Variance in					Nine Months Ended September 30,				Variance in
	2017		2016		Dollars			Percent		2017		2016		Dollars			Percent
Interest expense, net	$	3,826	$	3,874	$	(48	)		(1.2)%	$	9,157	$	16,643	$	(7,486	)		(45.0)%
Percentage of net sales		0.9%		0.9%							0.7%		1.4%

Interest expense, net remained relatively flat at $3.8 million for the three months ended September 30, 2017 from same period in 2016. Interest expense, net decreased $7.5 million to $9.2 million for the nine months ended September 30, 2017 from $16.6 million for the same period in 2016. The decrease in interest expense, net is primarily related to lower average interest rates resulting from the refinancing of our plant debt in late 2016.

Net Loss Available to Common Stockholders

The following table presents our net loss available to common stockholders in dollars and as a percentage of net sales (in thousands, except percentages):

	Three Months Ended September 30,				Variance in					Nine Months Ended September 30,				Variance in
	2017		2016		Dollars			Percent		2017		2016		Dollars		Percent
Net loss available to common stockholders	$	521	$	3,837	$	(3,316	)		(86.4)%	$	22,625	$	12,607	$	10,018		79.5%
Percentage of net sales		0.1%		0.9%							1.8%		1.1%

25

The changes in net loss available to common stockholders, was primarily due to changes in margins, partially offset by lower interest expense for the three and nine months ended September 30, 2017, as compared to the same period in 2016.

Liquidity and Capital Resources

During the nine months ended September 30, 2017, we funded our operations primarily from cash on hand, cash generated from our operations, tax refunds related to prior years, proceeds from term debt and advances under our revolving credit facilities. These funds were also used to make capital expenditures, complete the ICP acquisition, and make capital lease payments and principal payments on term debt and lines of credit.

Our current available capital resources consist of cash on hand and amounts available for borrowing under our credit facilities. We expect that our future available capital resources will consist primarily of our remaining cash balances, amounts available for borrowing, if any, under our credit facilities and cash generated from our operations.

We believe that current and future available capital resources, revenues generated from operations, and other existing sources of liquidity, including our credit facilities, will be adequate to meet our anticipated capital requirements for at least the next twelve months.

Quantitative Quarter-End Liquidity Status

We believe that the following amounts provide insight into our liquidity and capital resources. The following selected financial information should be read in conjunction with our consolidated financial statements and notes to consolidated financial statements included elsewhere in this report, and the other sections of “Management’s Discussion and Analysis of Financial Condition and Results of Operations” contained in this report (dollars in thousands):

	September 30, 2017		December 31, 2016		Change
Cash and cash equivalents	$	56,923	$	68,590		(17.0)%
Current assets	$	212,818	$	235,201		(9.5)%
Current liabilities	$	92,396	$	78,841		17.2%
Long-term debt, net of current portion	$	220,304	$	188,028		17.2%
Working capital	$	120,422	$	156,360		(23.0)%
Working capital ratio		2.30		2.98		(22.8)%

Restricted Net Assets

At September 30, 2017, we had $305.7 million of net assets at our subsidiaries that were not available to be transferred to Pacific Ethanol, Inc. in the form of dividends, loans or advances due to restrictions contained in the credit facilities of our subsidiaries.

Changes in Working Capital and Cash Flows

Working capital decreased to $120.4 million at September 30, 2017 from $156.4 million at December 31, 2016 as a result of a decrease of $22.4 million in current assets and an increase of $13.6 million in current liabilities.

Current assets decreased primarily due to decreases of $11.7 million in cash and cash equivalents, $14.0 million in accounts receivable due to the timing of sales volumes at the end of the period, $5.6 million in income tax receivables and $4.3 million in prepaid inventory, partially offset by an increase of $11.7 million in inventories and $2.0 million in derivative instrument assets.

Our cash and cash equivalents decreased by $11.7 million at September 30, 2017 as compared to December 31, 2016 due to $41.3 million of cash used in our investing activities, due to our acquisition of ICP and capital projects associated with our plant improvement initiatives, and $5.4 million of cash used in our financing activities, also primarily driven by our ICP acquisition, partially offset by $35.0 million of cash provided by our operations.

26

Our current liabilities increased primarily due to increases of $9.5 million in the current portion of our term debt and $6.1 million in accounts payable and accrued liabilities, partially offset by decreases of $1.4 million in derivative instrument liabilities and $0.7 million in other current liabilities.

Cash provided by our Operating Activities

Cash provided by our operating activities increased by $20.0 million for the nine months ended September 30, 2017 as compared to the same period in 2016. The increase in cash provided by our operating activities is primarily due to:

· a decrease in accounts receivable of $33.4 million primarily due to the timing of sales volumes at the end of the periods;

· a decrease in inventories and prepaid inventory of $8.3 million primarily due to the timing of purchases;

· a decrease in gains from derivative activities of $2.5 million due to market changes; and

· an increase in noncash compensation of $1.1 million due to stock grant activity in the current period;

These amounts were partially offset by:

· an increase in consolidated net loss of $12.3 million due to lower margins;

· a decrease in accounts payable and accrued expenses of $1.2 million resulting primarily from the period-over-period timing of payments;

· a decrease in interest expense added to term debt of $9.5 million; and

· an increase in prepaid expenses of $3.3 million due to the timing of payments.

Cash used in our Investing Activities

Cash used in our investing activities increased by $31.3 million for the nine months ended September 30, 2017 as compared to the same period in 2016. The increase in cash used in our investing activities is primarily due to $28.9 million in payments for our ICP acquisition, net of cash acquired in the acquisition, and proceeds from cash collateralized letters of credit in 2016 in the amount of $4.1 million that did not recur in 2017, partially offset by $1.7 million in lower spending on capital projects associated with our plant improvement initiatives.

Cash used in our Financing Activities

Cash used in our financing activities decreased by $11.8 million for the nine months ended September 30, 2017 as compared to the same period in 2016. The decrease in cash used in our financing activities is primarily due to $42.0 million in proceeds from our ICP credit facilities, $13.5 million in proceeds from our issuance of additional senior notes, $2.6 million in lower capital lease payments and $1.2 million in proceeds from warrant and option exercises, partially offset by a $37.9 million increase in principal payments on term notes and an $8.8 million increase in payments on Kinergy’s line of credit.

Kinergy Operating Line of Credit

Kinergy maintains an operating line of credit for an aggregate amount of up to $100.0 million. The credit facility expires on December 31, 2020. Interest accrues under the credit facility at a rate equal to (i) the three-month London Interbank Offered Rate (“LIBOR”), plus (ii) a specified applicable margin ranging from 1.50% to 2.00%. The credit facility’s monthly unused line fee is 0.25% to 0.375% of the amount by which the maximum credit under the facility exceeds the average daily principal balance during the immediately preceding month. Payments that may be made by Kinergy to Pacific Ethanol as reimbursement for management and other services provided by Pacific Ethanol to Kinergy are limited under the terms of the credit facility to $1.5 million per fiscal quarter. The credit facility also includes the accounts receivable of Pacific Ag. Products, LLC, or PAP, as additional collateral. Payments that may be made by PAP to Pacific Ethanol as reimbursement for management and other services provided by Pacific Ethanol to PAP are limited under the terms of the credit facility to $0.5 million per fiscal quarter. PAP, one of our indirect wholly-owned subsidiaries, markets our co-products and also provides raw material procurement services to our subsidiaries.

27

For all monthly periods in which excess borrowing availability falls below a specified level, Kinergy and PAP must collectively maintain a fixed-charge coverage ratio (calculated as a twelve-month rolling earnings before interest, taxes, depreciation and amortization (EBITDA), subject to certain adjustments, divided by the sum of interest expense, principal payments of indebtedness, indebtedness from capital leases and taxes paid during such twelve-month rolling period) of at least 2.0 and are prohibited from incurring certain additional indebtedness (other than specific intercompany indebtedness). Kinergy’s and PAP’s obligations under the credit facility are secured by a first-priority security interest in all of their assets in favor of the lender. Kinergy and PAP believe they are in compliance with this covenant. The following table summarizes Kinergy’s financial covenants and actual results for the periods presented (dollars in thousands). For all periods below, Kinergy maintained above the minimum excess availability required; accordingly, the fixed-charge coverage ratio covenant did not apply.

	Three Months Ended September 30,			Years Ended December 31,
		2017	2016		2016	2015
Fixed-Charge Coverage Ratio Requirement		2.00	2.00		2.00	2.00
Actual		3.01	9.38		7.88	10.02
Excess		1.01	7.38		5.88	8.02

Pacific Ethanol has guaranteed all of Kinergy’s obligations under the credit facility. As of September 30, 2017, Kinergy had an outstanding balance of $44.0 million with additional borrowing availability under the credit facility of $22.4 million.

Pekin Credit Facilities

Pacific Ethanol Pekin, Inc., or PE Pekin, has a $60.5 million term loan facility that matures on August 20, 2021 and a $32.0 million revolving credit facility that matures on February 1, 2022. The PE Pekin credit facilities are secured by a first-priority security interest in all of PE Pekin’s assets. Interest accrues under the PE Pekin credit facilities at an annual rate equal to the 30-day LIBOR plus 4.00%, payable monthly. PE Pekin is required to make quarterly principal payments in the amount of $3.5 million on the term loan beginning on August 20, 2017 and a principal payment of $4.5 million at maturity on August 20, 2021. PE Pekin is required to pay monthly in arrears a fee on any unused portion of the revolving credit facility at a rate of 0.75% per annum. Prepayment of these facilities is subject to a prepayment penalty. Under the terms of the credit facilities, PE Pekin is required to maintain working capital of not less than $17.5 million from August 31, 2017 through December 31, 2017 and working capital of not less than $20.0 million from January 1, 2018 and continuing at all times thereafter. In addition, PE Pekin is required to maintain an annual debt coverage ratio of not less than 0.15 to 1.0 for the year ending December 31, 2017 and 1.25 to 1.0 for years thereafter.

Pacific Aurora Credit Facility

Pacific Aurora maintains a revolving credit facility for up to $30.0 million that matures on February 1, 2022. The credit facility is secured by a first-priority security interest in all of Pacific Aurora’s assets. Borrowing availability under the credit facility automatically declines by $2.5 million on the first day of each June and December beginning on December 1, 2017 through and including December 1, 2020. Interest accrues under the Pacific Aurora credit facility at an annual rate equal to the 30-day LIBOR plus 4.0%, payable monthly. Pacific Aurora is required to pay monthly in arrears a fee on any unused portion of the credit facility at a rate of 0.75% per annum. Prepayment of the credit facility is subject to a prepayment penalty. Under the terms of the credit facility, Pacific Aurora is required to maintain not less than $18.0 million in working capital through February 28, 2018, not less than $20.0 million in working capital after February 28, 2018 and an annual debt coverage ratio of not less than 0.0 to 1.0 for the year ending December 31, 2017 and 1.5 to 1.0 for the year ending December 31, 2018. At September 30, 2017, Pacific Aurora had no amounts outstanding under the credit facility and $30.0 million available for borrowing under the facility.

ICP Credit Facilities

ICP has a $24.0 million term loan facility that matures on September 20, 2021 and an $18.0 million revolving credit facility that matures on September 1, 2022. The ICP credit facilities are secured by a first-priority security interest in all of ICP’s assets. Interest accrues under the ICP credit facilities at an annual rate equal to the 30-day LIBOR plus 3.75%, payable monthly. ICP is required to make quarterly principal payments in the amount of $1.5 million on the term loan beginning in December 2017. ICP is required to pay monthly in arrears a fee on any unused portion of the revolving credit facility at a rate of 0.75% per annum. Under the terms of the credit facilities, ICP is required to maintain working capital of not less than $8.0 million. In addition, ICP is required to maintain an annual debt coverage ratio of not less than 1.5 to 1.0 beginning for the year ending December 31, 2018.

28

Pacific Ethanol, Inc. Notes Payable

We have $68.9 million in aggregate principal amount of senior secured notes that mature on December 15, 2019. Interest on the notes accrues at an annual rate equal to (i) the greater of 1% and the three-month LIBOR, plus 7.0% through December 14, 2017, (ii) the greater of 1% and LIBOR, plus 9% between December 15, 2017 and December 14, 2018, and (iii) the greater of 1% and LIBOR plus 11% between December 15, 2018 and the maturity date. Interest is payable in cash in arrears on the 15th calendar day of each March, June, September and December beginning on March 15, 2017. We are required to pay all outstanding principal and any accrued and unpaid interest on the notes on the maturity date. We may, at our option, prepay the outstanding principal amount of the notes at any time without premium or penalty. Pacific Ethanol, Inc. issued the notes, which are secured by a first-priority security interest in the equity interest held by Pacific Ethanol, Inc. in its wholly-owned subsidiary, PE Op. Co., which indirectly owns our plants located on the West Coast.

Pacific Ethanol Central, LLC Notes Payable

We issued $46.9 million in aggregate principal amount of secured notes that were to mature on January 3, 2019 as part of the purchase price for our acquisition of ICP. On September 15, 2017, we repaid these notes with cash on hand and $42.0 million in proceeds from the ICP credit facilities.

Contractual Obligations

Except for ICP’s credit facilities, as discussed above, there have been no material changes in the nine months ended September 30, 2017 to the amounts presented in the table under the “Contractual Obligations” section in Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operation” of our Annual Report on Form 10-K for 2016.

Effects of Inflation

The impact of inflation was not significant to our financial condition or results of operations for the three and nine months ended September 30, 2017 and 2016.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.

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

Commodity Risk

We produce ethanol and ethanol co-products. Our business is sensitive to changes in the prices of ethanol and corn. In the ordinary course of business, we may enter into various types of transactions involving financial instruments to manage and reduce the impact of changes in ethanol and corn prices. We do not enter into derivatives or other financial instruments for trading or speculative purposes.

We are subject to market risk with respect to ethanol pricing. Ethanol prices are sensitive to global and domestic ethanol supply, crude-oil supply and demand; crude-oil refining capacity; carbon intensity; government regulation; and consumer demand for alternative fuels. Our ethanol sales are priced using contracts that are either based on a fixed price or an indexed price tied to a specific market, such as CBOT or the Oil Price Information Service. Under these fixed-priced arrangements, we are exposed to risk of an increase in the market price of ethanol between the time the price is fixed and the time the ethanol is sold.

We satisfy our physical corn needs, the principal raw material used to produce ethanol and ethanol co-products, based on supply-guaranteed contracts with our vendors. Generally, we determine the purchase price of our corn at the time we begin to grind that day’s needs. Sometimes we may also enter into contracts with our vendors to fix a portion of the purchase price of our corn requirements. As such, we are also subject to market risk with respect to the price of corn. The price of corn is subject to wide fluctuations due to unpredictable factors such as weather conditions, farmer planting decisions, governmental policies with respect to agriculture and international trade and global supply and demand. Under the fixed-price arrangements, we assume the risk of a decrease in the market price of corn between the time the price is fixed and the time the corn is utilized.

29

Ethanol co-products are sensitive to various demand factors such as numbers of livestock on feed, prices for feed alternatives, and supply factors, primarily production of ethanol co-products by ethanol plants and other sources.

As noted above, we may attempt to reduce the market risk associated with fluctuations in the price of ethanol or corn by employing a variety of risk management and hedging strategies. Strategies include the use of derivative financial instruments such as futures and options executed on the CBOT and/or the New York Mercantile Exchange, as well as the daily management of physical corn.

These derivatives are not designated for special hedge accounting treatment, and as such, the changes in the fair values of these exchanged-traded contracts are recorded on the balance sheet and recognized immediately in cost of goods sold. We recognized losses of $0.8 million and gains of $1.7 million related to settled non-designated hedges as the change in the fair values of these contracts for the nine months ended September 30, 2017 and 2016, respectively.

At September 30, 2017, we prepared a sensitivity analysis to estimate our exposure to ethanol and corn. Market risk related to these factors was estimated as the potential change in pre-tax income resulting from a hypothetical 10% adverse change in the prices of our expected ethanol and corn volumes. The results of this analysis as of September 30, 2017, which may differ materially from actual results, are as follows (in millions):

Commodity		Nine Months Ended September 30, 2017 Volume		Unit of Measure		Approximate Adverse Change to Pre-Tax Income
	Ethanol		624.7		Gallons	$	62.3
	Corn		133.6		Bushels	$	51.8

Interest Rate Risk

We are exposed to market risk from changes in interest rates. Exposure to interest rate risk results primarily from our indebtedness that bears interest at variable rates. At September 30, 2017, all of our long-term debt of $243.9 million was variable-rate in nature. Based on a 100 basis point (1.00%) increase in the interest rate on our long-term debt, pre-tax income for the nine months ended September 30, 2017 would be negatively impacted by approximately $1.8 million.

ITEM 4. CONTROLS AND PROCEDURES.

Evaluation of Disclosure Controls and Procedures

We conducted an evaluation under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures. The term “disclosure controls and procedures,” as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended, or Exchange Act, means controls and other procedures of a company that are designed to ensure that information required to be disclosed by the company in the reports it files or submits under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the Securities and Exchange Commission’s rules and forms. Disclosure controls and procedures also include, without limitation, controls and procedures designed to ensure that information required to be disclosed by a company in the reports that it files or submits under the Exchange Act is accumulated and communicated to the company’s management, including its principal executive and principal financial officers, or persons performing similar functions, as appropriate, to allow timely decisions regarding required disclosure. Based on this evaluation, our Chief Executive Officer and Chief Financial Officer concluded as of September 30, 2017 that our disclosure controls and procedures were effective at a reasonable assurance level.

30

Changes in Internal Control over Financial Reporting

There has been no change in our internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) during the most recently completed fiscal quarter that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

Inherent Limitations on the Effectiveness of Controls

Management does not expect that our disclosure controls and procedures or our internal control over financial reporting will prevent or detect all errors and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control systems are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in a cost-effective control system, no evaluation of internal control over financial reporting can provide absolute assurance that misstatements due to error or fraud will not occur or that all control issues and instances of fraud, if any, have been or will be detected.

These inherent limitations include the realities that judgments in decision-making can be faulty and that breakdowns can occur because of a simple error or mistake. Controls can also be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the controls. The design of any system of controls is based in part on certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions. Projections of any evaluation of controls effectiveness to future periods are subject to risks. Over time, controls may become inadequate because of changes in conditions or deterioration in the degree of compliance with policies or procedures.

31

PART II - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS.

We are subject to legal proceedings, claims and litigation arising in the ordinary course of business. While the amounts claimed may be substantial, the ultimate liability cannot presently be determined because of considerable uncertainties that exist. Therefore, it is possible that the outcome of those legal proceedings, claims and litigation could adversely affect our quarterly or annual operating results or cash flows when resolved in a future period. However, based on facts currently available, management believes such matters will not adversely affect in any material respect our financial position, results of operations or cash flows.

ITEM 1A. RISK FACTORS.

Before deciding to purchase, hold or sell our common stock, you should carefully consider the risks described below in addition to the other information contained in this Report and in our other filings with the Securities and Exchange Commission, including subsequent reports on Forms 10-Q and 8-K. The risks and uncertainties described below are not the only ones we face. Additional risks and uncertainties not presently known to us or that we currently deem immaterial may also affect our business. If any of these known or unknown risks or uncertainties actually occurs with material adverse effects on Pacific Ethanol, our business, financial condition, results of operations and/or liquidity could be seriously harmed. In that event, the market price for our common stock will likely decline, and you may lose all or part of your investment.

Risks Related to our Business

We have incurred significant losses and negative operating cash flow in the past and we may incur losses and negative operating cash flow in the future, which may hamper our operations and impede us from expanding our business.

We have incurred significant losses and negative operating cash flow in the past. For the nine months ended September 30, 2017 and 2016, and for the year ended December 31, 2015, we incurred consolidated net losses of approximately $24.0 million, $11.7 million and $18.9 million, respectively. For the year ended December 31, 2015, we incurred negative operating cash flows of $26.8 million. We may incur losses and negative operating cash flow in the future. We expect to rely on cash on hand, cash, if any, generated from our operations, borrowing availability under our lines of credit and proceeds from future financing activities, if any, to fund all of the cash requirements of our business. Continued losses and negative operating cash flow may hamper our operations and impede us from expanding our business.

Our results of operations and our ability to operate at a profit is largely dependent on managing the costs of corn and natural gas and the prices of ethanol, distillers grains and other ethanol co-products, all of which are subject to significant volatility and uncertainty.

Our results of operations are highly impacted by commodity prices, including the cost of corn and natural gas that we must purchase, and the prices of ethanol, distillers grains and other ethanol co-products that we sell. Prices and supplies are subject to and determined by market and other forces over which we have no control, such as weather, domestic and global demand, supply shortages, export prices and various governmental policies in the United States and around the world.

As a result of price volatility of corn, natural gas, ethanol, distillers grains and other ethanol co-products, our results of operations may fluctuate substantially. In addition, increases in corn or natural gas prices or decreases in ethanol, distillers grains or other ethanol co-product prices may make it unprofitable to operate. In fact, some of our marketing activities will likely be unprofitable in a market of generally declining ethanol prices due to the nature of our business. For example, to satisfy customer demands, we maintain certain quantities of ethanol inventory for subsequent resale. Moreover, we procure much of our inventory outside the context of a marketing arrangement and therefore must buy ethanol at a price established at the time of purchase and sell ethanol at an index price established later at the time of sale that is generally reflective of movements in the market price of ethanol. As a result, our margins for ethanol sold in these transactions generally decline and may turn negative as the market price of ethanol declines.

No assurance can be given that corn or natural gas can be purchased at, or near, current or any particular prices or that ethanol, distillers grains or other ethanol co-products will sell at, or near, current or any particular prices. Consequently, our results of operations and financial position may be adversely affected by increases in the price of corn or natural gas or decreases in the price of ethanol, distillers grains or other ethanol co-products.

32

Over the past several years, the spread between ethanol and corn prices has fluctuated significantly. Fluctuations are likely to continue to occur. A sustained narrow spread, whether as a result of sustained high or increased corn prices or sustained low or decreased ethanol prices, would adversely affect our results of operations and financial position. Further, combined revenues from sales of ethanol, distillers grains and other ethanol co-products could decline below the marginal cost of production, which may force us to suspend production of ethanol, distillers grains and ethanol co-products at some or all of our plants.

Increased ethanol production or higher inventory levels may cause a decline in ethanol prices or prevent ethanol prices from rising, and may have other negative effects, adversely impacting our results of operations, cash flows and financial condition.

We believe that the most significant factor influencing the price of ethanol has been the substantial increase in ethanol production in recent years. According to the Renewable Fuels Association, domestic ethanol production capacity increased from an annualized rate of 1.5 billion gallons per year in January 1999 to a record 16.0 billion gallons in 2016. In addition, if ethanol production margins improve, we anticipate that owners of ethanol production facilities will increase production levels, thereby resulting in more abundant ethanol supplies and inventories. Any increase in the demand for ethanol may not be commensurate with increases in the supply of ethanol, thus leading to lower ethanol prices. Also, demand for ethanol could be impaired due to a number of factors, including regulatory developments and reduced United States gasoline consumption. Reduced gasoline consumption has occurred in the past and could occur in the future as a result of increased gasoline or oil prices or other factors such as increased automobile fuel efficiency. Any of these outcomes could have a material adverse effect on our results of operations, cash flows and financial condition.

The market price of ethanol is volatile and subject to large fluctuations, which may cause our profitability or losses to fluctuate significantly.

The market price of ethanol is volatile and subject to large fluctuations. The market price of ethanol is dependent upon many factors, including the supply of ethanol and the price of gasoline, which is in turn dependent upon the price of petroleum which is highly volatile and difficult to forecast. For example, ethanol prices, as reported by the CBOT, ranged from $1.31 to $1.75 per gallon during 2016, $1.31 to $1.69 per gallon during 2015 and $1.50 to $3.52 per gallon during 2014. Fluctuations in the market price of ethanol may cause our profitability or losses to fluctuate significantly.

Some of our marketing activities will likely be unprofitable in a market of generally declining ethanol prices due to the nature of our business.

Some of our marketing activities will likely be unprofitable in a market of generally declining ethanol prices due to the nature of our business. For example, to satisfy customer demands, we maintain certain quantities of ethanol inventory for subsequent resale. Moreover, we procure much of our inventory outside the context of a marketing arrangement and therefore must buy ethanol at a price established at the time of purchase and sell ethanol at an index price established later at the time of sale that is generally reflective of movements in the market price of ethanol. As a result, our margins for ethanol sold in these transactions generally decline and may turn negative as the market price of ethanol declines.

Disruptions in ethanol production or distribution infrastructure may adversely affect our business, results of operations and financial condition.

Our business depends on the continuing availability of rail, road, port, storage and distribution infrastructure. In particular, due to limited storage capacity at our plants and other considerations related to production efficiencies, our plants depend on just-in-time delivery of corn. The production of ethanol also requires a significant and uninterrupted supply of other raw materials and energy, primarily water, electricity and natural gas. Local water, electricity and gas utilities may not be able to reliably supply the water, electricity and natural gas that our plants need or may not be able to supply those resources on acceptable terms. During 2014, poor weather caused disruptions in rail transportation, which slowed the delivery of ethanol by rail, the principle manner by which ethanol from our plants located in the Midwest is transported to market. Disruptions in the ethanol production or distribution infrastructure, whether caused by labor difficulties, earthquakes, storms, other natural disasters or human error or malfeasance or other reasons, could prevent timely deliveries of corn or other raw materials and energy, and could delay transport of our ethanol to market, and may require us to halt production at one or more plants, any of which could have a material adverse effect on our business, results of operations and financial condition.

33

We may engage in hedging transactions and other risk mitigation strategies that could harm our results of operations.

In an attempt to partially offset the effects of volatility of ethanol prices and corn and natural gas costs, we may enter into contracts to fix the price of a portion of our ethanol production or purchase a portion of our corn or natural gas requirements on a forward basis. In addition, we may engage in other hedging transactions involving exchange-traded futures contracts for corn, natural gas and unleaded gasoline from time to time. The financial statement impact of these activities is dependent upon, among other things, the prices involved and our ability to sell sufficient products to use all of the corn and natural gas for which forward commitments have been made. Hedging arrangements also expose us to the risk of financial loss in situations where the other party to the hedging contract defaults on its contract or, in the case of exchange-traded contracts, where there is a change in the expected differential between the underlying price in the hedging agreement and the actual prices paid or received by us. As a result, our results of operations and financial condition may be adversely affected by fluctuations in the price of corn, natural gas, ethanol and unleaded gasoline.

Operational difficulties at our plants could negatively impact sales volumes and could cause us to incur substantial losses.

Operations at our plants are subject to labor disruptions, unscheduled downtimes and other operational hazards inherent in the ethanol production industry, including equipment failures, fires, explosions, abnormal pressures, blowouts, pipeline ruptures, transportation accidents and natural disasters. Some of these operational hazards may cause personal injury or loss of life, severe damage to or destruction of property and equipment or environmental damage, and may result in suspension of operations and the imposition of civil or criminal penalties. Our insurance may not be adequate to fully cover the potential operational hazards described above or we may not be able to renew this insurance on commercially reasonable terms or at all.

Moreover, our plants may not operate as planned or expected. All of these facilities are designed to operate at or above a specified production capacity. The operation of these facilities is and will be, however, subject to various uncertainties. As a result, these facilities may not produce ethanol and its co-products at expected levels. In the event any of these facilities do not run at their expected capacity levels, our business, results of operations and financial condition may be materially and adversely affected.

Future demand for ethanol is uncertain and may be affected by changes to federal mandates, public perception, consumer acceptance and overall consumer demand for transportation fuel, any of which could negatively affect demand for ethanol and our results of operations.

Although many trade groups, academics and governmental agencies have supported ethanol as a fuel additive that promotes a cleaner environment, others have criticized ethanol production as consuming considerably more energy and emitting more greenhouse gases than other biofuels and potentially depleting water resources. Some studies have suggested that corn-based ethanol is less efficient than ethanol produced from other feedstock and that it negatively impacts consumers by causing increased prices for dairy, meat and other food generated from livestock that consume corn. Additionally, ethanol critics contend that corn supplies are redirected from international food markets to domestic fuel markets. If negative views of corn-based ethanol production gain acceptance, support for existing measures promoting use and domestic production of corn-based ethanol could decline, leading to reduction or repeal of federal mandates, which could adversely affect the demand for ethanol. These views could also negatively impact public perception of the ethanol industry and acceptance of ethanol as an alternative fuel.

There are limited markets for ethanol beyond those established by federal mandates. Discretionary blending and E85 blending are important secondary markets. Discretionary blending is often determined by the price of ethanol versus the price of gasoline. In periods when discretionary blending is financially unattractive, the demand for ethanol may be reduced. Also, the demand for ethanol is affected by the overall demand for transportation fuel. Demand for transportation fuel is affected by the number of miles traveled by consumers and the fuel economy of vehicles. Market acceptance of E15 may partially offset the effects of decreases in transportation fuel demand. A reduction in the demand for ethanol and ethanol co-products may depress the value of our products, erode our margins and reduce our ability to generate revenue or to operate profitably. Consumer acceptance of E15 and E85 fuels is needed before ethanol can achieve any significant growth in market share relative to other transportation fuels.

34

If we fail to integrate successfully the businesses of Pacific Ethanol and Illinois Corn Processing in the expected timeframe our results of operations will be adversely affected.

The success of the ICP acquisition will depend, in large part, on our ability to realize the anticipated benefits from combining the businesses of Pacific Ethanol and ICP. To realize these anticipated benefits, we must successfully integrate the businesses of Pacific Ethanol and ICP. This integration will be complex and time-consuming.

The failure to integrate successfully and to manage successfully the challenges presented by the integration process may result in our failure to achieve some or all of the anticipated benefits of the acquisition.

Potential difficulties that may be encountered in the integration process include the following:

· lost sales and customers as a result of customers of either of Pacific Ethanol or ICP deciding not to do business with us;

· complexities associated with managing the larger, more complex, combined business;

· integrating personnel;

· potential unknown liabilities and unforeseen expenses, delays or regulatory conditions associated with the acquisition; and

· performance shortfalls as a result of the diversion of management’s attention caused by integrating Pacific Ethanol’s and ICP’s operations.

Our future results will suffer if we do not effectively manage our expanded operations.

Our business following the ICP acquisition is larger than the individual businesses of Pacific Ethanol and ICP prior to the acquisition. Our future success depends, in part, upon our ability to manage our expanded business, which will pose challenges for our management, including challenges related to the management and monitoring of new operations and associated increased costs and complexity. We cannot assure you that we will be successful or that we will realize the expected operating efficiencies, annual net operating synergies, revenue enhancements and other benefits currently anticipated to result from the acquisition.

Our success will depend on relationships with third parties and pre-existing customers of Pacific Ethanol and ICP, which relationships may be affected by customer preferences or public attitudes about the ICP acquisition. Any adverse changes in these relationships could adversely affect our business, financial condition and results of operations.

Our success will depend on our ability to maintain and renew business relationships, including relationships with preexisting customers of both Pacific Ethanol and ICP, and to establish new business relationships. There can be no assurance that we will be able to maintain preexisting customer contracts and other business relationships, or enter into or maintain new customer contracts and other business relationships, on acceptable terms, if at all. The failure to maintain important business relationships could have a material adverse effect on our business, financial condition or results of operations.

Business issues faced by Pacific Ethanol or ICP may be imputed to our operations as a whole or to the operations of the other company.

To the extent that Pacific Ethanol or ICP has or is perceived by customers to have operational challenges or other business issues, those challenges or issues may raise concerns by existing customers as to our operations as a whole or as to the operations of the other company, which may limit or impede our ability to maintain relationships with those customers.

Our plant indebtedness exposes us to many risks that could negatively impact our business, our business prospects, our liquidity and our cash flows and results of operations.

Our plants located in the Midwest have significant indebtedness. Unlike traditional term debt, the terms of our plant loans require amortizing payments of principal over the lives of the loans and our borrowing availability under our plant credit facilities periodically and automatically declines through the maturity dates of those facilities. Our plant indebtedness could:

· make it more difficult to pay or refinance our debts as they become due during adverse economic and industry conditions because any decrease in revenues could cause us to not have sufficient cash flows from operations to make our scheduled debt payments;

· limit our flexibility to pursue strategic opportunities or react to changes in our business and the industry in which we operate and, consequently, place us at a competitive disadvantage to our competitors who have less debt;

· require a substantial portion of our cash flows from operations to be used for debt service payments, thereby reducing the availability of our cash flows to fund working capital, capital expenditures, acquisitions, dividend payments and other general corporate purposes; or

· limit our ability to procure additional financing for working capital or other purposes.

35

Our term loans and credit facilities also require compliance with numerous financial and other covenants. In addition, our plant indebtedness bears interest at variable rates. An increase in prevailing interest rates would likewise increase our debt service obligations and could materially and adversely affect our cash flows and results of operations.

Our ability to generate sufficient cash to make all principal and interest payments when due depends on our performance, which is subject to a variety of factors beyond our control, including the supply of and demand for ethanol and co-products, ethanol and co-product prices, the cost of key production inputs, and many other factors incident to the ethanol production and marketing industry. We cannot provide any assurance that we will be able to timely satisfy such obligations. Our failure to timely satisfy our debt obligations could have a material adverse effect on our business, business prospects, liquidity, cash flows and results of operations.

If Kinergy fails to satisfy its financial covenants under its credit facility, it may experience a loss or reduction of that facility, which would have a material adverse effect on our financial condition and results of operations.

We are substantially dependent on Kinergy’s credit facility to help finance its operations. Kinergy must satisfy monthly financial covenants under its credit facility, including fixed-charge coverage ratio covenants. Kinergy will be in default under its credit facility if it fails to satisfy any financial covenant. A default may result in the loss or reduction of the credit facility. The loss of Kinergy’s credit facility, or a significant reduction in Kinergy’s borrowing capacity under the facility, would result in Kinergy’s inability to finance a significant portion of its business and would have a material adverse effect on our financial condition and results of operations.

The United States ethanol industry is highly dependent upon certain federal and state legislation and regulation and any changes in legislation or regulation could have a material adverse effect on our results of operations, cash flows and financial condition.

The EPA has implemented the RFS pursuant to the Energy Policy Act of 2005 and the Energy Independence and Security Act of 2007. The RFS program sets annual quotas for the quantity of renewable fuels (such as ethanol) that must be blended into motor fuels consumed in the United States. The domestic market for ethanol is significantly impacted by federal mandates under the RFS program for volumes of renewable fuels (such as ethanol) required to be blended with gasoline. Future demand for ethanol will be largely dependent upon incentives to blend ethanol into motor fuels, including the relative price of gasoline versus ethanol, the relative octane value of ethanol, constraints in the ability of vehicles to use higher ethanol blends, the RFS, and other applicable environmental requirements. Any significant increase in production capacity above the RFS minimum requirements may have an adverse impact on ethanol prices.

Legislation aimed at reducing or eliminating the renewable fuel use required by the RFS has been introduced in the United States Congress. On January 3, 2017, the Leave Ethanol Volumes at Existing Levels (LEVEL) Act (H.R. 119) was introduced in the House of Representatives. The bill would freeze renewable fuel blending requirements under the RFS at 7.5 billion gallons per year, prohibit the sale of gasoline containing more than 10% ethanol, and revoke the EPA’s approval of E15 blends. On January 31, 2017, a bill (H.R. 777) was introduced in the House of Representatives that would require the EPA and National Academies of Sciences to conduct a study on “the implications of the use of mid-level ethanol blends”. A mid-level ethanol blend is an ethanol-gasoline blend containing 10-20% ethanol by volume, including E15 and E20, that is intended to be used in any conventional gasoline-powered motor vehicle or nonroad vehicle or engine. Also on January 31, 2017, a bill (H.R. 776) was introduced in the House of Representatives that would limit the volume of cellulosic biofuel required under the RFS to what is commercially available. On March 2, 2017, a bill (H.R. 1315) was introduced in the House of Representatives that would cap the volume of ethanol in gasoline at 10%. On the same day, the RFS Elimination Act (H.R. 1314) was introduced, which would fully repeal the RFS.

All of these bills were assigned to a congressional subcommittee, which will consider them before possibly sending any of them on to the House of Representatives as a whole. Our operations could be adversely impacted if any legislation is enacted that reduces or eliminates the RFS volume requirements or that reduces or eliminates corn ethanol as qualifying as a renewable fuel under the RFS.

Under the provisions of the Clean Air Act, as amended by the Energy Independence and Security Act of 2007, the EPA has limited authority to waive or reduce the mandated RFS requirements, which authority is subject to consultation with the Secretaries of Agriculture and Energy, and based on a determination that there is inadequate domestic renewable fuel supply or implementation of the applicable requirements would severely harm the economy or environment of a state, region or the United States. Our results of operations, cash flows and financial condition could be adversely impacted if the EPA reduces the RFS requirements from the statutory levels specified in the RFS.

36

The ethanol production and marketing industry is extremely competitive. Many of our significant competitors have greater production and financial resources and one or more of these competitors could use their greater resources to gain market share at our expense.

The ethanol production and marketing industry is extremely competitive. Many of our significant competitors in the ethanol production and marketing industry, including Archer Daniels Midland Company and Valero Energy Corporation, have substantially greater production and/or financial resources. As a result, our competitors may be able to compete more aggressively and sustain that competition over a longer period of time. Successful competition will require a continued high level of investment in marketing and customer service and support. Our limited resources relative to many significant competitors may cause us to fail to anticipate or respond adequately to new developments and other competitive pressures. This failure could reduce our competitiveness and cause a decline in market share, sales and profitability. Even if sufficient funds are available, we may not be able to make the modifications and improvements necessary to compete successfully.

We also face competition from international suppliers. Currently, international suppliers produce ethanol primarily from sugar cane and have cost structures that are generally substantially lower than our cost structures. Any increase in domestic or foreign competition could cause us to reduce our prices and take other steps to compete effectively, which could adversely affect our business, financial condition and results of operations.

Our ability to utilize net operating loss carryforwards and certain other tax attributes may be limited.

Federal and state income tax laws impose restrictions on the utilization of net operating loss, or NOL, and tax credit carryforwards in the event that an “ownership change” occurs for tax purposes, as defined by Section 382 of the Internal Revenue Code, or Code. In general, an ownership change occurs when stockholders owning 5% or more of a “loss corporation” (a corporation entitled to use NOL or other loss carryovers) have increased their ownership of stock in such corporation by more than 50 percentage points during any three-year period. The annual base limitation under Section 382 of the Code is calculated by multiplying the loss corporation’s value at the time of the ownership change by the greater of the long-term tax-exempt rate determined by the Internal Revenue Service in the month of the ownership change or the two preceding months.

As of December 31, 2016, of our $117.7 million of federal NOLs, we had $101.4 million of federal NOLs that are limited in their annual use under Section 382 of the Code. Accordingly, our ability to utilize these NOL carryforwards may be substantially limited. These limitations could in turn result in increased future tax obligations, which could have a material adverse effect on our business, financial condition and results of operations.

Our business is not diversified. The high concentration of our sales within the ethanol production and marketing industry could result in a significant reduction in sales and negatively affect our profitability if demand for ethanol declines.

We expect to be completely focused on the production and marketing of ethanol and its co-products for the foreseeable future. We may be unable to shift our business focus away from the production and marketing of ethanol to other renewable fuels or competing products. Accordingly, an industry shift away from ethanol or the emergence of new competing products may reduce the demand for ethanol. A downturn in the demand for ethanol would likely materially and adversely affect our sales and profitability.

We may be adversely affected by environmental, health and safety laws, regulations and liabilities.

We are subject to various federal, state and local environmental laws and regulations, including those relating to the discharge of materials into the air, water and ground, the generation, storage, handling, use, transportation and disposal of hazardous materials and wastes, and the health and safety of our employees. In addition, some of these laws and regulations require us to operate under permits that are subject to renewal or modification. These laws, regulations and permits can often require expensive pollution control equipment or operational changes to limit actual or potential impacts to the environment. A violation of these laws and regulations or permit conditions can result in substantial fines, natural resource damages, criminal sanctions, permit revocations and/or facility shutdowns. In addition, we have made, and expect to make, significant capital expenditures on an ongoing basis to comply with increasingly stringent environmental laws, regulations and permits.

37

We may be liable for the investigation and cleanup of environmental contamination at each of our plants and at off-site locations where we arrange for the disposal of hazardous substances or wastes. If these substances or wastes have been or are disposed of or released at sites that undergo investigation and/or remediation by regulatory agencies, we may be responsible under the Comprehensive Environmental Response, Compensation and Liability Act of 1980, or other environmental laws for all or part of the costs of investigation and/or remediation, and for damages to natural resources. We may also be subject to related claims by private parties alleging property damage and personal injury due to exposure to hazardous or other materials at or from those properties. Some of these matters may require us to expend significant amounts for investigation, cleanup or other costs.

In addition, new laws, new interpretations of existing laws, increased governmental enforcement of environmental laws or other developments could require us to make significant additional expenditures. Continued government and public emphasis on environmental issues can be expected to result in increased future investments for environmental controls at our plants. Present and future environmental laws and regulations, and interpretations of those laws and regulations, applicable to our operations, more vigorous enforcement policies and discovery of currently unknown conditions may require substantial expenditures that could have a material adverse effect on our results of operations and financial condition.

The hazards and risks associated with producing and transporting our products (including fires, natural disasters, explosions and abnormal pressures and blowouts) may also result in personal injury claims or damage to property and third parties. As protection against operating hazards, we maintain insurance coverage against some, but not all, potential losses. However, we could sustain losses for uninsurable or uninsured risks, or in amounts in excess of existing insurance coverage. Events that result in significant personal injury or damage to our property or third parties or other losses that are not fully covered by insurance could have a material adverse effect on our results of operations and financial condition.

If we are unable to attract or retain key personnel, including as a result of the ICP acquisition, our ability to operate effectively may be impaired, which could have a material adverse effect on our business, financial condition and results of operations.

Our ability to operate our business and implement strategies depends, in part, on the efforts of our executive officers and other key personnel. Our future success will depend on, among other factors, our ability to retain our current key personnel and attract and retain qualified future key personnel, particularly executive management. In addition, the success of the ICP acquisition will depend in part on our ability to retain key personnel. It is possible that these personnel might decide not to remain with us now that the acquisition is completed. If these key personnel terminate their employment, our business activities might be adversely affected and management’s attention might be diverted from integrating the businesses of Pacific Ethanol and ICP to recruiting suitable replacement personnel. If we are unable to attract or retain key personnel, our ability to operate effectively may be impaired, which could have a material adverse effect on our business, financial condition and results of operations.

We depend on a small number of customers for the majority of our sales. A reduction in business from any of these customers could cause a significant decline in our overall sales and profitability.

The majority of our sales are generated from a small number of customers. During 2016, 2015 and 2014, three customers accounted for an aggregate of approximately $572 million, $467 million and $569 million in net sales, representing 35%, 39% and 51% of our net sales, respectively, for those periods. We expect that we will continue to depend for the foreseeable future upon a small number of customers for a significant portion of our sales. Our agreements with these customers generally do not require them to purchase any specified volume or dollar value of ethanol or co-products, or to make any purchases whatsoever. Therefore, in any future period, our sales generated from these customers, individually or in the aggregate, may not equal or exceed historical levels. If sales to any of these customers cease or decline, we may be unable to replace these sales with sales to either existing or new customers in a timely manner, or at all. A cessation or reduction of sales to one or more of these customers could cause a significant decline in our overall sales and profitability.

38

Our lack of long-term ethanol orders and commitments by our customers could lead to a rapid decline in our sales and profitability.

We cannot rely on long-term ethanol orders or commitments by our customers for protection from the negative financial effects of a decline in the demand for ethanol or a decline in the demand for our marketing services. The limited certainty of ethanol orders can make it difficult for us to forecast our sales and allocate our resources in a manner consistent with our actual sales. Moreover, our expense levels are based in part on our expectations of future sales and, if our expectations regarding future sales are inaccurate, we may be unable to reduce costs in a timely manner to adjust for sales shortfalls. Furthermore, because we depend on a small number of customers for a significant portion of our sales, the magnitude of the ramifications of these risks is greater than if our sales were less concentrated. As a result of our lack of long-term ethanol orders and commitments, we may experience a rapid decline in our sales and profitability.

There are limitations on our ability to receive distributions from our subsidiaries.

We conduct most of our operations through subsidiaries and are dependent upon dividends or other intercompany transfers of funds from our subsidiaries to generate free cash flow. Moreover, some of our subsidiaries are limited in their ability to pay dividends or make distributions, loans or advances to us by the terms of their financing arrangements. At September 30, 2017, we had approximately $305.7 million of net assets at our subsidiaries that were not available to be distributed in the form of dividends, distributions, loans or advances due to restrictions contained in their financing arrangements.

Risks Related to Ownership of our Common Stock

Our stock price is highly volatile, which could result in substantial losses for investors purchasing shares of our common stock and in litigation against us.

The market price of our common stock has fluctuated significantly in the past and may continue to fluctuate significantly in the future. The market price of our common stock may continue to fluctuate in response to one or more of the following factors, many of which are beyond our control:

· fluctuations in the market prices of ethanol and its co-products;

· the cost of key inputs to the production of ethanol, including corn and natural gas;

· the volume and timing of the receipt of orders for ethanol from major customers;

· competitive pricing pressures;

· our ability to timely and cost-effectively produce, sell and deliver ethanol;

· the announcement, introduction and market acceptance of one or more alternatives to ethanol;

· changes in market valuations of companies similar to us;

· stock market price and volume fluctuations generally;

· the possibility that the anticipated benefits from our acquisition of ICP cannot be fully realized in a timely manner or at all, or that integrating the acquired operations will be more difficult, disruptive or costly than anticipated;

· regulatory developments or increased enforcement;

· fluctuations in our quarterly or annual operating results;

· additions or departures of key personnel;

· our ability to obtain any necessary financing;

· our financing activities and future sales of our common stock or other securities; and

· our ability to maintain contracts that are critical to our operations.

Demand for ethanol could be adversely affected by a slow-down in the overall demand for oxygenate and gasoline additive products. The levels of our ethanol production and purchases for resale will be based upon forecasted demand. Accordingly, any inaccuracy in forecasting anticipated revenues and expenses could adversely affect our business. The failure to receive anticipated orders or to complete delivery in any quarterly period could adversely affect our results of operations for that period. Quarterly and annual results are not necessarily indicative of future performance for any particular period, and we may not experience revenue growth or profitability on a quarterly or an annual basis.

39

The price at which you purchase shares of our common stock may not be indicative of the price that will prevail in the trading market. You may be unable to sell your shares of common stock at or above your purchase price, which may result in substantial losses to you and which may include the complete loss of your investment. In the past, securities class action litigation has often been brought against a company following periods of high stock price volatility. We may be the target of similar litigation in the future. Securities litigation could result in substantial costs and divert management’s attention and our resources away from our business.

Any of the risks described above could have a material adverse effect on our results of operations or the price of our common stock, or both.

The ICP acquisition may not be accretive to, and may instead reduce, our earnings per share, which may negatively affect the market price of our common stock.

Although the ICP acquisition is expected to be accretive to earnings per share, the acquisition may not be accretive to, and may instead reduce, our earnings per share. The expectation that the acquisition will be accretive is based on preliminary estimates that may materially change. All of the risk factors applicable to the ethanol industry and our business as a marketer and producer of ethanol are also be applicable to ICP’s business. In addition, future events and conditions could decrease or delay any accretion, result in dilution or cause greater dilution than may be expected, including:

· adverse changes in market conditions;

· commodity prices for corn, ethanol, specialty alcohols, gasoline and crude oil;

· production levels;

· operating results;

· competitive conditions;

· laws and regulations affecting the ethanol and specialty alcohol businesses;

· capital expenditure obligations; and

· general economic conditions.

Any decrease or delay of any accretion to our earnings per share, or any reduction in our earnings per share, as a result of our ICP acquisition could cause the price of our common stock to decline.

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

Unregistered Sales of Equity Securities

None.

Dividends

Our current and future debt financing arrangements may limit or prevent cash distributions from our subsidiaries to us, depending upon the achievement of specified financial and other operating conditions and our ability to properly service our debt, thereby limiting or preventing us from paying cash dividends.

At September 30, 2017, we had $305.7 million of net assets at our subsidiaries that were not available to be transferred to Pacific Ethanol, Inc. in the form of dividends, loans or advances due to restrictions contained in the credit facilities of our subsidiaries.

For each of the three months ended September 30, 2017 and 2016, we declared and paid in cash an aggregate of $0.3 million in dividends on our Series B Cumulative Convertible Preferred Stock, or Series B Preferred Stock. We have never declared or paid cash dividends on our common stock and do not currently intend to pay cash dividends on our common stock in the foreseeable future. We currently anticipate that we will retain any earnings for use in the continued development of our business. The holders of our outstanding Series B Preferred Stock are entitled to dividends of 7% per annum, payable quarterly. Dividends in respect of our Series B Preferred Stock must be paid prior to the payment of any dividends in respect of our common stock.

40

ITEM 3. DEFAULTS UPON SENIOR SECURITIES.

Not applicable.

ITEM 4. MINE SAFETY DISCLOSURES.

Not applicable.

ITEM 5. OTHER INFORMATION.

None.

41

ITEM 6. EXHIBITS.

Exhibit Number	Description (**)
10.1	Promissory Note issued to Illinois Corn Processing Holdings Inc. on July 3, 2017 (1)
10.2	Promissory Note issued to MGPI Processing, Inc. on July 3, 2017 (1)
10.3	Second Amended and Restated Loan and Security Agreement dated August 2, 2017 by and among Kinergy Marketing LLC, Pacific Ag. Products, LLC, the parties thereto from time to time as Lenders and Wells Fargo Bank, National Association (2)
10.4	Second Amended and Restated Guarantee dated August 2, 2017 by Pacific Ethanol, Inc. in favor of Wells Fargo Bank, National Association for and on behalf of the Lenders (2)
10.5	Amendment No. 2 to Credit Agreement dated August 7, 2017 by and between Pacific Ethanol Pekin, LLC, Compeer Financial, PCA and CoBank, ACB (3)
10.6	Credit Agreement dated September 15, 2017 by and between Illinois Corn Processing, LLC, Compeer Financial, PCA and CoBank, ACB (4)
10.7	Term Note dated September 15, 2017 by Illinois Corn Processing, LLC in favor of Compeer Financial, PCA (4)
10.8	Revolving Term Note dated September 15, 2017 by Illinois Corn Processing, LLC in favor of Compeer Financial, PCA (4)
10.9	Illinois Future Advance Real Estate Mortgage dated September 15, 2017 by Illinois Corn Processing, LLC in favor of CoBank, ACB (4)
10.10	Security Agreement dated September 15, 2017 by Illinois Corn Processing, LLC in favor of CoBank, ACB (4)
31.1	Certifications Required by Rule 13a-14(a) of the Securities Exchange Act of 1934, as amended, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (*)
31.2	Certifications Required by Rule 13a-14(a) of the Securities Exchange Act of 1934, as amended, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (*)
32.1	Certification of Chief Executive Officer and Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (*)

42

101.INS	XBRL Instance Document (*)
101.SCH	XBRL Taxonomy Extension Schema (*)
101.CAL	XBRL Taxonomy Extension Calculation Linkbase (*)
101.DEF	XBRL Taxonomy Extension Definition Linkbase (*)
101.LAB	XBRL Taxonomy Extension Label Linkbase (*)
101.PRE	XBRL Taxonomy Extension Presentation Linkbase (*)

____________________

(*) Filed herewith.

(**) Certain of the agreements filed as exhibits contain representations and warranties made by the parties thereto. The assertions embodied in such representations and warranties are not necessarily assertions of fact, but a mechanism for the parties to allocate risk. Accordingly, investors should not rely on the representations and warranties as characterizations of the actual state of facts or for any other purpose at the time they were made or otherwise.

(1) Previously filed as an exhibit to the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on July 5, 2017.

(2) Previously filed as an exhibit to the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on August 8, 2017.

(3) Previously filed as an exhibit to the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on August 11, 2017.

(4) Previously filed as an exhibit to the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on September 21, 2017.

43

SIGNATURES

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

	PACIFIC ETHANOL, INC.
Dated: November 9, 2017	By: /S/ BRYON T. MCGREGOR
	Bryon T. McGregor
	Chief Financial Officer
	(Principal Financial and Accounting Officer)

44

EXHIBITS FILED WITH THIS REPORT

Exhibit Number	Description
31.1	Certification Required by Rule 13a-14(a) of the Securities Exchange Act of 1934, as amended, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2	Certification Required by Rule 13a-14(a) of the Securities Exchange Act of 1934, as amended, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.1	Certification of Chief Executive Officer and Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema
101.CAL	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	XBRL Taxonomy Extension Definition Linkbase
101.LAB	XBRL Taxonomy Extension Label Linkbase
101.PRE	XBRL Taxonomy Extension Presentation Linkbase

____________________

45

EX-31.1

EXHIBIT 31.1

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Neil M. Koehler, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Pacific Ethanol, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: November 9, 2017

/S/ NEIL M. KOEHLER

Neil M. Koehler

President and Chief Executive Officer

(Principal Executive Officer)

EX-31.2

EXHIBIT 31.2

CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Bryon T. McGregor, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Pacific Ethanol, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: November 9, 2017

/S/ BRYON T. MCGREGOR

Bryon T. McGregor

Chief Financial Officer

(Principal Financial Officer)

EX-32.1

EXHIBIT 32.1

CERTIFICATION OF
CHIEF EXECUTIVE OFFICER AND CHIEF FINANCIAL OFFICER
PURSUANT TO 18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of Pacific Ethanol, Inc. (the “Company”) for the period ended September 30, 2017 (the “Report”), the undersigned hereby certify in their capacities as Chief Executive Officer and Chief Financial Officer of the Company, respectively, pursuant to 18 U.S.C. section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.       the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

2.       the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated:  November 9, 2017	By: /S/ NEIL M. KOEHLER
	Neil M. Koehler
	President and Chief Executive Officer
	(Principal Executive Officer)
Dated:  November 9, 2017	By: /S/ BRYON T. MCGREGOR
	Bryon T. McGregor
	Chief Financial Officer
	(Principal Financial Officer)

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signatures that appear in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2017	Nov. 08, 2017
Document And Entity Information
Entity Registrant Name	Pacific Ethanol, Inc.
Entity Central Index Key	0000778164
Document Type	10-Q
Document Period End Date	Sep. 30, 2017
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		43,971,127
Trading Symbol	PEIX
Document Fiscal Period Focus	Q3
Document Fiscal Year Focus	2017

XML

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Current Assets:
Cash and cash equivalents	$ 56,923	$ 68,590
Accounts receivable, net (net of allowance for doubtful accounts of $18 and $331, respectively)	72,282	86,275
Inventories	71,819	60,070
Prepaid inventory	5,622	9,946
Income tax receivables	129	5,730
Derivative Instruments	3,017	978
Other current assets	3,026	3,612
Total current assets	212,818	235,201
Property and equipment, net	509,369	465,190
Other Assets:
Intangible assets, net	2,678	2,678
Other assets	5,785	5,169
Total other assets	8,463	7,847
Total Assets	730,650	708,238
Current Liabilities:
Accounts payable - trade	41,178	37,051
Accrued liabilities	22,245	20,280
Current portion - capital leases	799	794
Current portion - long-term debt	20,000	10,500
Derivative instruments	2,755	4,115
Accrued PE Op Co. purchase	3,828	3,828
Other current liabilities	1,591	2,273
Total current liabilities	92,396	78,841
Long-term debt, net of current portion	220,304	188,028
Capital leases, net of current portion	134	547
Warrant liabilities at fair value	0	651
Other liabilities	20,915	21,910
Total Liabilities	333,749	289,977
Pacific Ethanol, Inc. Stockholders' Equity:
Common stock, $0.001 par value; 300,000 shares authorized; 43,971 and 39,772 shares issued and outstanding as of September 30, 2017 and December 31, 2016, respectively	44	40
Non-voting common stock, $0.001 par value; 3,553 shares authorized; 1 and 3,540 shares issued and outstanding as of September 30, 2017 and December 31, 2016, respectively	0	4
Additional paid-in capital	926,248	922,698
Accumulated other comprehensive (loss)	(2,620)	(2,620)
Accumulated deficit	(554,858)	(532,233)
Total Pacific Ethanol, Inc. Stockholders' Equity	368,815	387,890
Noncontrolling interests	28,086	30,371
Total Stockholders' Equity	396,901	418,261
Total Liabilities and Stockholders' Equity	730,650	708,238
Series A Preferred Stock [Member]
Pacific Ethanol, Inc. Stockholders' Equity:
Preferred stock, $0.001 par value; 10,000 shares authorized	0	0
Series B Preferred Stock [Member]
Pacific Ethanol, Inc. Stockholders' Equity:
Preferred stock, $0.001 par value; 10,000 shares authorized	$ 1	$ 1

XML

Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) shares in Thousands, $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Accounts receivable, net of allowance	$ 18	$ 331
Preferred stock, par value	$ 0.001	$ 0.001
Preferred stock, shares authorized	10,000	10,000
Common stock, par value	$ 0.001	$ 0.001
Common stock, shares authorized	300,000	300,000
Common stock, shares issued	43,971	39,772
Common stock, shares outstanding	43,971	39,772
Series A Preferred Stock [Member]
Preferred stock, shares authorized	1,684	1,684
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Series B Preferred Stock [Member]
Preferred stock, shares authorized	1,581	1,581
Preferred stock, shares issued	927	927
Preferred stock, shares outstanding	927	927
Liquidation preference	$ 18,075
Nonvoting Common Stock [Member]
Common stock, par value	$ 0.001	$ 0.001
Common stock, shares authorized	3,553	3,553
Common stock, shares issued	1	3,540
Common stock, shares outstanding	1	3,540

XML

Consolidated Statements of Operations (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Income Statement [Abstract]
Net sales	$ 445,442	$ 417,806	$ 1,236,984	$ 1,183,039
Cost of goods sold	433,377	411,442	1,229,039	1,157,902
Gross profit	12,065	6,364	7,945	25,137
Selling, general and administrative expenses	8,720	5,971	22,932	20,436
Income (loss) from operations	3,345	393	(14,987)	4,701
Fair value adjustments	0	(69)	473	(53)
Interest expense, net	(3,826)	(3,874)	(9,157)	(16,643)
Other income (expense), net	(60)	32	(293)	92
Loss before provision (benefit) for income taxes	(541)	(3,518)	(23,964)	(11,903)
Provision (benefit) for income taxes	0	0	0	(245)
Consolidated net loss	(541)	(3,518)	(23,964)	(11,658)
Net loss attributed to noncontrolling interests	339	0	2,285	0
Net loss attributed to Pacific Ethanol, Inc.	(202)	(3,518)	(21,679)	(11,658)
Preferred stock dividends	(319)	(319)	(946)	(949)
Net loss available to common stockholders	$ (521)	$ (3,837)	$ (22,625)	$ (12,607)
Net loss per share, basic and diluted	$ (0.01)	$ (0.09)	$ (0.53)	$ (0.30)
Weighted average number of shares outstanding, basic and diluted	42,475	42,226	42,358	42,156

XML

Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Operating Activities:
Consolidated net loss	$ (23,964)	$ (11,658)
Adjustments to reconcile consolidated net loss to net cash provided by operating activities:
Depreciation and amortization of intangibles	28,486	26,526
Interest expense added to term debt	0	9,451
Fair value adjustments	(473)	53
Amortization of debt discount	454	930
Amortization of deferred financing fees	339	97
Non-cash compensation	2,985	1,888
Loss (gain) on derivative instruments	836	(1,669)
Bad debt expense	4	325
Changes in operating assets and liabilities, net of effects from acquisition of ICP:
Accounts receivable	25,625	(7,803)
Inventories	(1,891)	(4,168)
Prepaid expenses and other assets	2,197	5,503
Prepaid inventory	4,397	(1,657)
Accounts payable and accrued expenses	(3,995)	(2,789)
Net cash provided by operating activities	35,000	15,029
Investing Activities:
Additions to property and equipment	(12,348)	(14,045)
Purchase of ICP, net of cash acquired	(28,921)	0
Proceeds from cash collateralized letters of credit	0	4,113
Net cash used in investing activities	(41,269)	(9,932)
Financing Activities:
Net (payments) proceeds from Kinergy’s line of credit	(5,889)	2,913
Proceeds from ICP credit facilities	42,000	0
Proceeds from assessment financing	1,144	1,020
Net proceeds from notes	13,530	0
Payments for debt issuance costs	(924)	0
Principal payments on borrowings	(54,927)	(17,003)
Payments on capital leases	(588)	(3,151)
Proceeds from exercise of warrants and options	1,202	0
Preferred stock dividends paid	(946)	(949)
Net cash used in financing activities	(5,398)	(17,170)
Net decrease in cash and cash equivalents	(11,667)	(12,073)
Cash and cash equivalents at beginning of period	68,590	52,712
Cash and cash equivalents at end of period	56,923	40,639
Supplemental Information:
Interest paid	8,291	7,256
Income taxes received	5,601	4,784
Noncash financing and investing activities:
Issuance of notes payable for acquisition of ICP	46,927	0
Reclass of warrant liability to equity upon warrant exercises	$ 178	$ 0

XML

1. Organization and Basis of Presentation

9 Months Ended

Sep. 30, 2017

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization and Basis of Presentation

Organization and Business – The consolidated financial statements include, for all periods presented, the accounts of Pacific Ethanol, Inc., a Delaware corporation (“Pacific Ethanol”), and its direct and indirect subsidiaries (collectively, the “Company”), including its wholly-owned subsidiaries, Kinergy Marketing LLC, an Oregon limited liability company (“Kinergy”), Pacific Ag. Products, LLC, a California limited liability company (“PAP”), PE Op Co., a Delaware corporation (“PE Op Co.”) and eight of the Company’s ethanol production facilities. The Company’s acquisition of Illinois Corn Processing, LLC (“ICP”) was consummated on July 3, 2017, and as a result, the Company’s consolidated financial statements include the results of ICP commencing July 3, 2017 and all other periods presented exclude the results of ICP prior to that date. See Note 2 – Acquisition of ICP.

On December 15, 2016, the Company and Aurora Cooperative Elevator Company, a Nebraska cooperative corporation (“ACEC”), closed a transaction under a contribution agreement under which the Company contributed its Aurora, Nebraska ethanol facilities and ACEC contributed its Aurora grain elevator and related grain handling assets to Pacific Aurora, LLC (“Pacific Aurora”) in exchange for equity interests in Pacific Aurora. On December 15, 2016, concurrently with the closing under the contribution agreement, the Company sold a portion of its equity interest in Pacific Aurora to ACEC. As a result, as of December 15, 2016 and through September 30, 2017, the Company owned 73.93% of Pacific Aurora and ACEC owned 26.07% of Pacific Aurora. The Company consolidates 100% of the results of Pacific Aurora and records ACEC’s 26.07% equity interest as noncontrolling interests in the accompanying financial statements.

The Company is a leading producer and marketer of low-carbon renewable fuels and high-quality alcohol products in the United States. The Company owns and operates nine production facilities, four in the Western states of California, Oregon and Idaho, and five in the Midwestern states of Illinois and Nebraska. The Company’s four ethanol plants in the Western United States (together with their respective holding companies, the “Pacific Ethanol West Plants”) are located in close proximity to both feed and ethanol customers and thus enjoy unique advantages in efficiency, logistics and product pricing. These plants produce among the lowest-carbon ethanol produced in the United States due to low energy use in production.

The Company has production capacity of 605 million gallons per year, markets, on an annualized basis, nearly 1.0 billion gallons of ethanol, and produces, on an annualized basis, over 2.5 million tons of co-products such as wet and dry distillers grains, wet and dry corn gluten feed, condensed distillers solubles, corn gluten meal, corn germ, dried yeast and CO₂. The Company’s five ethanol plants in the Midwest (together with their respective holding companies, the “Pacific Ethanol Central Plants”) are located in the heart of the Corn Belt, benefit from low-cost and abundant feedstock production and allow for access to many additional domestic markets. In addition, the Company’s ability to load unit trains from these facilities in the Midwest, and barges from its Pekin, Illinois plants, allows for greater access to international markets.

Basis of Presentation–Interim Financial Statements – The accompanying unaudited consolidated financial statements and related notes have been prepared in accordance with accounting principles generally accepted in the United States for interim financial information and the instructions to Form 10-Q and Rule 10-01 of Regulation S-X. Results for interim periods should not be considered indicative of results for a full year. These interim consolidated financial statements should be read in conjunction with the consolidated financial statements and related notes contained in the Company’s Annual Report on Form 10-K for the year ended December 31, 2016. The accounting policies used in preparing these consolidated financial statements are the same as those described in Note 1 to the consolidated financial statements in the Company’s Annual Report on Form 10-K for the year ended December 31, 2016. In the opinion of management, all adjustments (consisting of normal recurring adjustments) considered necessary for a fair statement of the results for interim periods have been included. All significant intercompany accounts and transactions have been eliminated in consolidation.

Accounts Receivable and Allowance for Doubtful Accounts – Trade accounts receivable are presented at face value, net of the allowance for doubtful accounts. The Company sells ethanol to gasoline refining and distribution companies, sells distillers grains and other feed co-products to dairy operators and animal feedlots and sells corn oil to poultry and biodiesel customers generally without requiring collateral.

The Company maintains an allowance for doubtful accounts for balances that appear to have specific collection issues. The collection process is based on the age of the invoice and requires attempted contacts with the customer at specified intervals. If, after a specified number of days, the Company has been unsuccessful in its collection efforts, a bad debt allowance is recorded for the balance in question. Delinquent accounts receivable are charged against the allowance for doubtful accounts once uncollectibility has been determined. The factors considered in reaching this determination are the apparent financial condition of the customer and the Company’s success in contacting and negotiating with the customer. If the financial condition of the Company’s customers were to deteriorate, resulting in an impairment of ability to make payments, additional allowances may be required.

Of the accounts receivable balance, approximately $57,237,000 and $64,853,000 at September 30, 2017 and December 31, 2016, respectively, were used as collateral under Kinergy’s operating line of credit. The allowance for doubtful accounts was $18,000 and $331,000 as of September 30, 2017 and December 31, 2016, respectively. The Company recorded a bad debt expense of $2,000 and $39,000 for the three months ended September 30, 2017 and 2016, respectively. The Company recorded a bad debt expense of $4,000 and $325,000 for the nine months ended September 30, 2017 and 2016, respectively. The Company does not have any off-balance sheet credit exposure related to its customers.

Provision for Income Taxes – The Company recognized no tax benefit for the three and nine months ended September 30, 2017 due to the uncertainty of using its tax losses to offset future taxable income. The Company recognized a tax benefit of $0.2 million for the nine months ended September 30, 2016, as the Company has finalized certain of its tax returns. The Company applied a valuation allowance against the amount of deferred tax losses from the periods. To the extent the Company believes it can utilize these losses, it will adjust its provision (benefit) for income taxes accordingly in future periods.

Financial Instruments – The carrying values of cash and cash equivalents, accounts receivable, accounts payable, accrued liabilities and accrued PE Op Co. purchase are reasonable estimates of their fair values because of the short maturity of these items. The Company recorded its warrant liabilities at fair value. The Company believes the carrying value of its long-term debt approximates fair value because the interest rates on these instruments are variable, and are considered Level 2 fair value measurements.

Recent Accounting Pronouncements – In February 2016, the Financial Accounting Standards Board (“FASB”) issued new guidance on accounting for leases. Under the new guidance, lessees will be required to recognize the following for all leases (with the exception of short-term leases) at the commencement date: (1) a lease liability, which is a lessee’s obligation to make lease payments arising from a lease, measured on a discounted cash flow basis; and (2) a “right of use” asset, which is an asset that represents the lessee’s right to use the specified asset for the lease term. Under the new guidance, lessor accounting is largely unchanged, with some minor exceptions. Lessees will no longer be provided with a source of off-balance sheet financing for other than short-term leases. The standard is effective for public companies for annual reporting periods beginning after December 15, 2019, and for interim periods beginning after December 15, 2020. Early adoption is permitted. The Company has several operating leases that may be impacted by this guidance. The Company is currently evaluating the impact of the adoption of this accounting standard on its consolidated results of operations and financial condition.

In May 2014, the FASB issued new guidance (“ASC 606”) on the recognition of revenue. ASC 606 states that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The standard is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. In March and April 2016, the FASB issued further revenue recognition guidance amending principal vs. agent considerations regarding whether an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services.

The provisions of ASC 606 include a five-step process by which an entity will determine revenue recognition, depicting the transfer of goods or services to customers in amounts reflecting the payment to which an entity expects to be entitled in exchange for those goods or services. ASC 606 requires the Company to apply the following steps: (1) identify the contract with the customer; (2) identify the performance obligations in the contract; (3) determine the transaction price; (4) allocate the transaction price to the performance obligations in the contract; and (5) recognize revenue when, or as, the Company satisfies the performance obligation.

The Company will adopt ASC 606 on January 1, 2018. The Company is currently in the process of completing an evaluation of the new requirements, under ASC 606, on each of its major revenue types. The Company’s initial preliminary assessment indicates that ASC 606 will not materially change the way the Company accounts for its contracts with its customers, which will continue to be recognized at a point in time. The Company anticipates finalizing its assessment of the financial impact of ASC 606 during the fourth quarter of 2017 and anticipates adopting the new guidance using the modified retrospective transition method.

In April 2016, the FASB issued new guidance to reduce the complexity of certain aspects of accounting for employee share-based payment transactions. Prior to adoption of the standard, accruals of compensation costs were based on an estimated forfeiture rate. The new guidance allows an entity to make an entity-wide accounting policy election to either continue using an estimate of forfeitures or account for forfeitures only when they occur. The guidance is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. Effective January 1, 2017, the Company elected to discontinue the use of an estimated forfeiture rate and instead account for actual forfeitures as they occur. The transition guidance requires an adjustment to retained earnings for any cumulative effect. The impact to the Company upon adoption was determined to be immaterial.

Estimates and Assumptions – The preparation of the consolidated financial statements in conformity with U.S. generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates are required as part of determining the fair value of warrants, allowance for doubtful accounts, net realizable value of inventory, estimated lives of property and equipment, long-lived asset impairments, valuation allowances on deferred income taxes and the potential outcome of future tax consequences of events recognized in the Company’s financial statements or tax returns, and the valuation of assets acquired and liabilities assumed as a result of business combinations. Actual results and outcomes may materially differ from management’s estimates and assumptions.

XML

2. Acquisition Of ICP

9 Months Ended

Sep. 30, 2017

Business Combinations [Abstract]

Acquisition Of ICP

On June 26, 2017, the Company, through its wholly-owned direct and indirect subsidiaries PE Central, and ICP Merger Sub, LLC, a Delaware limited liability company and a direct wholly-owned subsidiary of PE Central (“Merger Sub”), entered into an Agreement and Plan of Merger (the “Merger Agreement”) with ICP, Illinois Corn Processing Holdings Inc. (“ICPH”) and MGPI Processing, Inc. (together with ICPH, the “Sellers”) to acquire 100% of the equity interests of ICP. The acquisition of ICP under the Merger Agreement was closed on July 3, 2017. At the closing, Merger Sub merged with and into ICP (the “Merger”), and ICP continues as the surviving corporation of the Merger and as a wholly-owned direct subsidiary of PE Central and a wholly-owned indirect subsidiary of the Company.

Upon closing and under the terms of the Merger Agreement, Merger Sub (i) paid to the Sellers $30,000,000 in cash, and (ii) issued to the Sellers secured promissory notes in the aggregate principal amount of approximately $46,927,000 (the “Seller Notes”). The Seller Notes were secured by a first priority lien on the assets of ICP and a pledge of the membership interests of ICP.

ICP is a 90 million gallon per year fuel and industrial alcohol manufacturing, storage and distribution facility adjacent to the Pacific Ethanol Pekin facility and is located on the Illinois River. ICP produces fuel-grade ethanol, beverage and industrial-grade alcohol, dry distillers grain (DDG) and corn oil. The facility has direct access to end-markets via barge, rail, and truck, and expands Pacific Ethanol’s domestic and international distribution channels.

The Company has recognized the following allocation of the purchase price at fair values. The following fair value allocation for all assets and liabilities is provisional and incomplete as the Company is in the process of completing its valuation of the assets acquired and liabilities assumed, most significantly its valuation of property and equipment, sellers notes and any income tax impact. The fair value of property and equipment is based on the Company’s draft valuations, and represents its best estimates at the time of the filing of this report. The Company expects to conclude its valuations during the fourth quarter of 2017. Preliminarily, no intangible assets or liabilities have been estimated due to ICP’s contracts being materially close to market prices. A final valuation may include either an asset or liability associated with any material out-of-market contract positions. Based upon these assumptions, the preliminary purchase price consideration allocation is as follows (in thousands):

Cash and equivalents	$	1,079
Accounts receivable		11,636
Inventories		9,858
Other current assets		907
Total current assets		23,480
Property and equipment		60,497
Other assets		328
Total assets acquired	$	84,305
Accounts payable, trade	$	5,683
Other current liabilities		1,486
Total current liabilities		7,169
Other non-current liabilities		209
Total liabilities assumed	$	7,378
Net assets acquired	$	76,927
Estimated goodwill	$	–
Total purchase price	$	76,927

The contractual amount due on the accounts receivable acquired was $11.6 million, all of which is expected to be collectible. Any changes to the initial estimates of the fair value of the acquired assets and assumed liabilities will be recorded as adjustments to those assets and liabilities and residual amounts will be allocated to goodwill if the net assets acquired are less than the purchase price. If the net assets acquired exceed the purchase price, the residual amount will result in a bargain purchase gain.

The following table presents unaudited pro forma combined financial information assuming the acquisition occurred on January 1, 2016.

	Three Months Ended September 30,			Nine Months Ended September 30,
	2016			2017			2016
Revenues – pro forma	$	461,825		$	1,315,046		$	1,317,243
Net loss – pro forma	$	(3,302	)	$	(27,145	)	$	(10,110	)
Diluted net income (loss) per share – pro forma	$	(0.08	)	$	(0.64	)	$	(0.24	)
Diluted weighted-average shares – pro forma		42,226			42,358			42,156

For the three and nine months ended September 30, 2017, ICP contributed $38.2 million in net revenues and $1.4 million in pre-tax income. For the three and nine months ended September 30, 2017, the Company recorded approximately $0.3 million in costs associated with the ICP acquisition. These costs are reflected in selling, general and administrative expenses on the Company’s consolidated statements of operations.

XML

3. Segments

9 Months Ended

Sep. 30, 2017

Segment Reporting [Abstract]

Segments

The Company reports its financial and operating performance in two segments: (1) ethanol production, which includes the production and sale of ethanol, specialty alcohols and co-products, with all of the Company’s production facilities aggregated, and (2) marketing and distribution, which includes marketing and merchant trading for Company-produced ethanol, specialty alcohols and co-products and third-party ethanol.

The following tables set forth certain financial data for the Company’s operating segments (in thousands):

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Net Sales
Ethanol Production:
Net sales to external customers	$	304,812		$	266,299		$	804,012		$	767,171
Intersegment net sales		639			306			1,138			829
Total ethanol production net sales	$	305,451		$	266,605		$	805,150		$	768,000
Marketing and distribution:
Net sales to external customers	$	140,630		$	151,507		$	432,972		$	415,868
Intersegment net sales		2,334			2,018			6,135			5,861
Total marketing and distribution net sales		142,964			153,525			439,107			421,729
Intersegment eliminations		(2,973	)		(2,324	)		(7,273	)		(6,690	)
Net sales as reported	$	445,442		$	417,806		$	1,236,984		$	1,183,039

Cost of goods sold:
Ethanol production	$	292,743		$	262,964		$	797,277		$	759,210
Marketing and distribution		142,303			153,406			437,110			412,225
Intersegment eliminations		(1,669	)		(4,928	)		(5,348	)		(13,533	)
Cost of goods sold as reported	$	433,377		$	411,442		$	1,229,039		$	1,157,902

Income (loss) before provision for income taxes:
Ethanol production	$	2,638		$	(2,903	)	$	(15,981	)	$	(19,171	)
Marketing and distribution		(757	)		(1,524	)		(2,043	)		4,654
Corporate activities		(2,422	)		909			(5,940	)		2,614
	$	(541	)	$	(3,518	)	$	(23,964	)	$	(11,903	)
Depreciation and amortization:
Ethanol production	$	9,841		$	8,631		$	27,703		$	25,839
Marketing and distribution		–			–			–			3
Corporate activities		238			226			783			684
	$	10,079		$	8,857		$	28,486		$	26,526
Interest expense:
Ethanol production	$	1,850		$	3,521		$	4,061		$	15,600
Marketing and distribution		342			353			952			1,043
Corporate activities		1,634			–			4,144			–
	$	3,826		$	3,874		$	9,157		$	16,643

The following table sets forth the Company’s total assets by operating segment (in thousands): 

	September 30, 2017		December 31, 2016
Total assets:
Ethanol production	$	596,928	$	542,688
Marketing and distribution		129,294		146,356
Corporate assets		4,428		19,194
	$	730,650	$	708,238

XML

4. Inventories

9 Months Ended

Sep. 30, 2017

Inventory Disclosure [Abstract]

Inventories

Inventories consisted primarily of bulk ethanol, corn, co-products, Low-Carbon Fuel Standard (“LCFS”) credits and unleaded fuel, and are valued at the lower of cost and net realizable value, with cost determined on a first-in, first-out basis.

Inventory balances consisted of the following (in thousands):

	September 30, 2017		December 31, 2016
Finished goods	$	46,314	$	33,773
Work in progress		9,637		7,092
Raw materials		8,401		6,571
LCFS credits		5,892		10,926
Other		1,575		1,708
Total	$	71,819	$	60,070

XML

5. Derivatives

9 Months Ended

Sep. 30, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives

The business and activities of the Company expose it to a variety of market risks, including risks related to changes in commodity prices. The Company monitors and manages these financial exposures as an integral part of its risk management program. This program recognizes the unpredictability of financial markets and seeks to reduce the potentially adverse effects that market volatility could have on operating results.

Commodity Risk – Cash Flow Hedges – The Company uses derivative instruments to protect cash flows from fluctuations caused by volatility in commodity prices for periods of up to twelve months to protect gross profit margins from potentially adverse effects of market and price volatility on ethanol sale and purchase commitments where the prices are set at a future date and/or if the contracts specify a floating or index-based price for ethanol. In addition, the Company hedges anticipated sales of ethanol to minimize its exposure to the potentially adverse effects of price volatility. These derivatives may be designated and documented as cash flow hedges and effectiveness is evaluated by assessing the probability of the anticipated transactions and regressing commodity futures prices against the Company’s purchase and sales prices. Ineffectiveness, which is defined as the degree to which the derivative does not offset the underlying exposure, is recognized immediately in cost of goods sold. For the three and nine months ended September 30, 2017 and 2016, the Company did not designate any of its derivatives as cash flow hedges.

Commodity Risk – Non-Designated Hedges – The Company uses derivative instruments to lock in prices for certain amounts of corn and ethanol by entering into exchange-traded forward contracts for those commodities. These derivatives are not designated for special hedge accounting treatment. The changes in fair value of these contracts are recorded on the balance sheet and recognized immediately in cost of goods sold. The Company recognized losses of $483,000 and gains of $859,000 as the changes in the fair values of these contracts for the three months ended September 30, 2017 and 2016, respectively. The Company recognized losses of $836,000 and gains of $1,669,000 as the changes in the fair values of these contracts for the nine months ended September 30, 2017 and 2016, respectively.

Non Designated Derivative Instruments – The classification and amounts of the Company’s derivatives not designated as hedging instruments are as follows (in thousands):

	As of September 30, 2017
	Assets			Liabilities
Type of Instrument	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity contracts	Derivative instruments	$	3,017	Derivative instruments	$	2,755

	As of December 30, 2016
	Assets			Liabilities
Type of Instrument	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity contracts	Derivative instruments	$	978	Derivative instruments	$	4,115

The classification and amounts of the Company’s recognized gains (losses) for its derivatives not designated as hedging instruments are as follows (in thousands):

		Realized Gains (Losses)
		Three Months Ended September 30,
Type of Instrument	Statements of Operations Location	2017			2016
Commodity contracts	Cost of goods sold	$	(1,576	)	$	2,242

		Unrealized Gains (Losses)
		Three Months Ended September 30,
Type of Instrument	Statements of Operations Location	2017		2016
Commodity contracts	Cost of goods sold	$	1,093	$	(1,383	)

		Realized Gains (Losses)
		Nine Months Ended September 30,
Type of Instrument	Statements of Operations Location	2017			2016
Commodity contracts	Cost of goods sold	$	(4,495	)	$	2,152

		Unrealized Gains (Losses)
		Nine Months Ended September 30,
Type of Instrument	Statements of Operations Location	2017		2016
Commodity contracts	Cost of goods sold	$	3,659	$	(483	)

XML

6. Debt

9 Months Ended

Sep. 30, 2017

Debt Disclosure [Abstract]

Debt

Long-term borrowings are summarized as follows (in thousands):

	September 30, 2017			December 31, 2016
Kinergy line of credit	$	43,973		$	49,862
Pekin term loan		57,000			64,000
Pekin revolving loan		32,000			32,000
ICP term loan		24,000			–
ICP revolving loan		18,000			–
Pacific Aurora line of credit		–			1,000
Parent notes payable		68,948			55,000
		243,921			201,862
Less unamortized debt discount		(1,590	)		(1,626	)
Less unamortized debt financing costs		(2,027	)		(1,708	)
Less short-term portion		(20,000	)		(10,500	)
Long-term debt	$	220,304		$	188,028

Kinergy Operating Line of Credit – On August 2, 2017, Kinergy increased its revolving line of credit from $85 million to $100 million. As of September 30, 2017, Kinergy had additional borrowing availability under its credit facility of $22,410,000.

Changes to Pekin Credit Facilities — On August 7, 2017, PE Pekin amended its term and revolving credit facilities by agreeing to increase the interest rate under the facilities by 25 basis points to an annual rate equal to the 30-day LIBOR plus 4.00%. PE Pekin and its lender also agreed that PE Pekin is required to maintain working capital of not less than $17.5 million from August 31, 2017 through December 31, 2017 and working capital of not less than $20.0 million from January 1, 2018 and continuing at all times thereafter. In addition, the required Debt Service Coverage Ratio was reduced to 0.15 to 1.00 for the fiscal year ending December 31, 2017.

ICP Credit Facilities — On September 15, 2017, ICP, Compeer Financial, PCA (“Lender”), and CoBank, ACB (“Agent”) entered into a Credit Agreement (“ICP Credit Agreement”). Under the ICP Credit Agreement, the Lender agreed to extend to ICP a term loan in the amount of $24,000,000 and a revolving loan in an amount of up to $18,000,000.

Under the term loan, ICP is to use the proceeds of the loan to refinance the Seller Notes. ICP is to make amortizing principal payments in sixteen equal consecutive quarterly installments of $1,500,000 each until September 20, 2021, at which time the entire remaining balance is due and payable. Interest on the unpaid principal amount of the term loan accrues at a rate equal to 3.75% plus the one-month LIBOR index rate.

Under the revolving loan, ICP is to use the proceeds of the revolving term facility to refinance the Seller Notes and for ICP’s working capital needs. The revolving loan matures on September 1, 2022. The revolving loan gives ICP the right, in ICP’s sole discretion, to permanently reduce from time to time the revolving term commitment in increments of $500,000 by giving the Agent ten days prior written notice.

The revolving loan requires ICP to pay the Agent a nonrefundable commitment fee equal to 0.75% per annum multiplied by the average daily positive difference between the amounts of (i) the revolving term commitment, minus (ii) the aggregate principal amount of all loans outstanding under the revolving loan. Interest on the unpaid principal amount of the loan accrues, pursuant to ICP’s election of the LIBOR Index Option, at a rate equal to 3.75% plus the one-month LIBOR index rate.

Under the terms of the credit facilities, ICP is required to maintain working capital of not less than $8.0 million. In addition, ICP is required to maintain an annual debt coverage ratio of not less than 1.5 to 1.0 beginning for the year ending December 31, 2018.

Changes to Pacific Aurora Credit Facility — On September 1, 2017, Pacific Aurora and its lender agreed that Pacific Aurora is required to maintain working capital of not less than $18.0 million from September 30, 2017 through February 28, 2018 and working capital of not less than $20.0 million from March 1, 2018 and continuing at all times thereafter. In addition, the required Debt Service Coverage Ratio was reduced to 0.00 to 1.00 for the fiscal year ending December 31, 2017 and 1.50 to 1.00 for the fiscal year ending December 31, 2018.

Parent Notes Payable – On June 26, 2017, the Company entered into a Note Purchase Agreement (the “Note Purchase Agreement”) with five accredited investors (the “Investors”) and a related Consent of Holders and Amendment of Senior Secured Notes with the Investors and holders of the Company’s senior secured notes issued on December 15, 2016 (“Prior Senior Notes”). On June 30, 2017, under the terms of the Note Purchase Agreement, the Company sold $13,948,000 in aggregate principal amount of its senior secured notes (the “Senior Notes”) to the Investors in a private offering for aggregate gross proceeds of 97% of the principal amount of the Senior Notes sold. Upon issuance, the Company recorded $418,000 in unamortized debt discount.

Distribution Restrictions – At September 30, 2017, there were $305,660,000 of net assets of the Company’s subsidiaries that were not available to be transferred to Pacific Ethanol in the form of dividends, loans or advances due to restrictions contained in the credit facilities of the Company’s subsidiaries.

XML

7. Warrants and stock options

9 Months Ended

Sep. 30, 2017

Notes to Financial Statements

Warrants and stock options

Warrant and Option Exercises – During the nine months ended September 30, 2017, certain holders exercised warrants and options and received an aggregate of 201,000 shares of the Company’s common stock upon payment of an aggregate of $1,201,000 in cash. There were no warrants or options exercised during the three months ended September 30, 2017 and the three and nine months ended September 30, 2016. As of September 30, 2017, there were no warrants outstanding for which we account using fair value methodologies; accordingly, no fair value adjustments will be made in future periods relating to currently outstanding warrants.

XML

8. Commitments and Contingencies

9 Months Ended

Sep. 30, 2017

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Sales Commitments – At September 30, 2017, the Company had entered into sales contracts with its major customers to sell certain quantities of ethanol and co-products. The Company had open ethanol indexed-price contracts for 224,150,000 gallons of ethanol as of September 30, 2017 and open fixed-price ethanol sales contracts totaling $53,672,000 as of September 30, 2017. The Company had open fixed-price co-product sales contracts totaling $30,375,000 and open indexed-price co-product sales contracts for 16,000 tons as of September 30, 2017. These sales contracts are scheduled to be completed through 2018.

Purchase Commitments – At September 30, 2017, the Company had indexed-price purchase contracts to purchase 20,050,000 gallons of ethanol and fixed-price purchase contracts to purchase $9,476,000 of ethanol from its suppliers. The Company had $11,000,000 of fixed-price corn purchase contracts and basis contracts with its suppliers as of September 30, 2017. These purchase commitments are scheduled to be satisfied through 2018.

Litigation – General – The Company is subject to various claims and contingencies in the ordinary course of its business, including those related to litigation, business transactions, employee-related matters, and others. When the Company is aware of a claim or potential claim, it assesses the likelihood of any loss or exposure. If it is probable that a loss will result and the amount of the loss can be reasonably estimated, the Company will record a liability for the loss. If the loss is not probable or the amount of the loss cannot be reasonably estimated, the Company discloses the claim if the likelihood of a potential loss is reasonably possible and the amount involved could be material. While there can be no assurances, the Company does not expect that any of its pending legal proceedings will have a material impact on the Company’s financial condition or results of operations.

The Company assumed certain legal matters which were ongoing at July 1, 2015, the date of the Company’s acquisition of Aventine Renewable Energy Holdings, Inc (“PE Central”). Among them were lawsuits between Aventine Renewable Energy, Inc. (now known as Pacific Ethanol Pekin, LLC, or “PE Pekin”) and Glacial Lakes Energy, Aberdeen Energy and Redfield Energy, together, the “Defendants,” in which PE Pekin sought damages for breach of termination agreements that wound down ethanol marketing arrangements between PE Pekin and each of the Defendants. In February and March 2017, the Company and the Defendants entered into settlement agreements and the Defendants paid in cash to the Company $3.9 million in final resolution of these matters. The Company did not assign any value to the claims against the Defendants in its accounting for the Aventine acquisition as of July 1, 2015. The Company recorded a gain, net of legal fees, of $3.6 million upon receipt of the cash settlement and recognized the gain in selling, general and administrative expenses in the consolidated statements of operations for the nine months ended September 30, 2017.

XML

9. Pension Plans

9 Months Ended

Sep. 30, 2017

Retirement Benefits [Abstract]

Pension Plans

The Company sponsors a defined benefit pension plan (the “Retirement Plan”) and a health care and life insurance plan (the “Postretirement Plan”). The Company assumed the Retirement Plan and the Postretirement Plan as part of its acquisition of PE Central on July 1, 2015.

The Retirement Plan is noncontributory, and covers only “grandfathered” unionized employees at the Company’s Pekin, Illinois facility who fulfill minimum age and service requirements. Benefits are based on a prescribed formula based upon the employee’s years of service. The Retirement Plan, which is part of a collective bargaining agreement, covers only union employees hired prior to November 1, 2010.

The Company uses a December 31 measurement date for its Retirement Plan. The Company’s funding policy is to make the minimum annual contributions that are required by applicable regulations. As of December 31, 2016, the Retirement Plan’s accumulated projected benefit obligation was $18.5 million, with a fair value of plan assets of $12.4 million. The underfunded amount of $6.1 million is recorded on the Company’s consolidated balance sheet in other noncurrent liabilities.

The Company’s net periodic Retirement Plan costs are as follows (in thousands):

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Interest cost	$	98		$	172		$	293		$	516
Service cost		188			56			563			168
Expected return on plan assets		(169	)		(199	)		(506	)		(597	)
Net periodic expense	$	117		$	29		$	350		$	87

The Postretirement Plan provides postretirement medical benefits and life insurance to certain “grandfathered” unionized employees. Employees hired after December 31, 2000 are not eligible to participate in the Postretirement Plan. The Postretirement Plan is contributory, with contributions required at the same rate as active employees. Benefit eligibility under the plan reduces at age 65 from a defined benefit to a defined dollar cap based upon years of service. As of December 31, 2016, the Postretirement Plan’s accumulated projected benefit obligation was $5.4 million and is recorded on the Company’s consolidated balance sheet in other noncurrent liabilities. The Company’s funding policy is to make the minimum annual contributions that are required by applicable regulations.

The Company’s net periodic Postretirement Plan costs are as follows (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
Interest cost	$	21	$	35	$	63	$	105
Service cost		50		12		150		36
Amortization of (gain) loss		33		–		99		–
Net periodic expense	$	104	$	47	$	312	$	141

XML

10. Fair Value Measurements

9 Months Ended

Sep. 30, 2017

Fair Value Disclosures [Abstract]

Fair Value Measurements

The fair value hierarchy prioritizes the inputs used in valuation techniques into three levels, as follows:

· Level 1 – Observable inputs – unadjusted quoted prices in active markets for identical assets and liabilities;

· Level 2 – Observable inputs other than quoted prices included in Level 1 that are observable for the asset or liability through corroboration with market data; and

· Level 3 – Unobservable inputs – includes amounts derived from valuation models where one or more significant inputs are unobservable. For fair value measurements using significant unobservable inputs, a description of the inputs and the information used to develop the inputs is required along with a reconciliation of Level 3 values from the prior reporting period.

Warrants – The Company’s warrants were valued using a Monte Carlo Binomial Lattice-Based valuation methodology, adjusted for marketability restrictions. The Company recorded its warrants issued in 2012 at fair value and designated them as Level 3 on their issuance dates.

Significant assumptions used and related fair values for the warrants as of December 31, 2016 were as follows:

Original Issuance	Exercise Price	Volatility	Risk Free Interest Rate	Term (years)	Market Discount	Warrants Outstanding	Fair Value
07/3/2012	$6.09	40.9%	0.62%	0.50	11.3%	211,000	$651,000

Other Derivative Instruments – The Company’s other derivative instruments consist of commodity positions. The fair values of the commodity positions are based on quoted prices on the commodity exchanges and are designated as Level 1 inputs.

The following table summarizes recurring fair value measurements by level at September 30, 2017 (in thousands):

	Fair
	Value			Level 1			Level 2		Level 3
Assets:
Derivative instruments	$	3,017		$	3,017		$	–	$	–
	$	3,017		$	3,017		$	–	$	–
Liabilities:
Warrants	$	–		$	–		$	–	$	–
Derivative instruments		(2,755	)		(2,755	)		–		–
	$	(2,755	)	$	(2,755	)	$	–	$	–

The changes in the Company’s fair value of its Level 3 inputs with respect to its warrants were as follows (in thousands):

Balance, December 31, 2016	$	651
Exercised warrants		(178	)
Adjustments to fair value for the period		(473	)
Balance, September 30, 2017	$	–

XML

11. Earnings Per Share

9 Months Ended

Sep. 30, 2017

Earnings Per Share [Abstract]

Earnings Per Share

The following tables compute basic and diluted earnings per share (in thousands, except per share data):

	Three Months Ended September 30, 2017
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(202	)
Less: Preferred stock dividends		(319	)
Basic and diluted loss per share:
Loss available to common stockholders	$	(521	)		42,475	$	(0.01	)

	Three Months Ended September 30, 2016
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(3,518	)
Less: Preferred stock dividends		(319	)
Basic and diluted loss per share:
Loss available to common stockholders	$	(3,837	)		42,226	$	(0.09	)

	Nine Months Ended September 30, 2017
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(21,679	)
Less: Preferred stock dividends		(946	)
Basic and diluted loss per share:
Loss available to common stockholders	$	(22,625	)		42,358	$	(0.53	)

	Nine Months Ended September 30, 2016
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(11,658	)
Less: Preferred stock dividends		(949	)
Basic and diluted loss per share:
Loss available to common stockholders	$	(12,607	)		42,156	$	(0.30	)

There were an aggregate of 688,000 and 737,000 potentially dilutive weighted-average shares from the Company’s warrants and shares of Series B Cumulative Convertible Preferred Stock outstanding for the three and nine months ended September 30, 2017, respectively. These convertible securities were not considered in calculating diluted net loss per share for the three and nine months ended September 30, 2017, as their effect would have been anti-dilutive.

XML

1. Organization and Basis of Presentation (Policies)

9 Months Ended

Sep. 30, 2017

Accounting Policies [Abstract]

Organization and Business

Organization and Business – The consolidated financial statements include, for all periods presented, the accounts of Pacific Ethanol, Inc., a Delaware corporation (“Pacific Ethanol”), and its direct and indirect subsidiaries (collectively, the “Company”), including its wholly-owned subsidiaries, Kinergy Marketing LLC, an Oregon limited liability company (“Kinergy”), Pacific Ag. Products, LLC, a California limited liability company (“PAP”), PE Op Co., a Delaware corporation (“PE Op Co.”) and eight of the Company’s ethanol production facilities. The Company’s acquisition of Illinois Corn Processing, LLC (“ICP”) was consummated on July 3, 2017, and as a result, the Company’s consolidated financial statements include the results of ICP commencing July 3, 2017 and all other periods presented exclude the results of ICP prior to that date. See Note 2 – Acquisition of ICP.

On December 15, 2016, the Company and Aurora Cooperative Elevator Company, a Nebraska cooperative corporation (“ACEC”), closed a transaction under a contribution agreement under which the Company contributed its Aurora, Nebraska ethanol facilities and ACEC contributed its Aurora grain elevator and related grain handling assets to Pacific Aurora, LLC (“Pacific Aurora”) in exchange for equity interests in Pacific Aurora. On December 15, 2016, concurrently with the closing under the contribution agreement, the Company sold a portion of its equity interest in Pacific Aurora to ACEC. As a result, as of December 15, 2016 and through September 30, 2017, the Company owned 73.93% of Pacific Aurora and ACEC owned 26.07% of Pacific Aurora. The Company consolidates 100% of the results of Pacific Aurora and records ACEC’s 26.07% equity interest as noncontrolling interests in the accompanying financial statements.

The Company is a leading producer and marketer of low-carbon renewable fuels and high-quality alcohol products in the United States. The Company owns and operates nine production facilities, four in the Western states of California, Oregon and Idaho, and five in the Midwestern states of Illinois and Nebraska. The Company’s four ethanol plants in the Western United States (together with their respective holding companies, the “Pacific Ethanol West Plants”) are located in close proximity to both feed and ethanol customers and thus enjoy unique advantages in efficiency, logistics and product pricing. These plants produce among the lowest-carbon ethanol produced in the United States due to low energy use in production.

The Company has production capacity of 605 million gallons per year, markets, on an annualized basis, nearly 1.0 billion gallons of ethanol, and produces, on an annualized basis, over 2.5 million tons of co-products such as wet and dry distillers grains, wet and dry corn gluten feed, condensed distillers solubles, corn gluten meal, corn germ, dried yeast and CO₂. The Company’s five ethanol plants in the Midwest (together with their respective holding companies, the “Pacific Ethanol Central Plants”) are located in the heart of the Corn Belt, benefit from low-cost and abundant feedstock production and allow for access to many additional domestic markets. In addition, the Company’s ability to load unit trains from these facilities in the Midwest, and barges from its Pekin, Illinois plants, allows for greater access to international markets.

Basis of Presentation-Interim Financial Statements

Basis of Presentation–Interim Financial Statements – The accompanying unaudited consolidated financial statements and related notes have been prepared in accordance with accounting principles generally accepted in the United States for interim financial information and the instructions to Form 10-Q and Rule 10-01 of Regulation S-X. Results for interim periods should not be considered indicative of results for a full year. These interim consolidated financial statements should be read in conjunction with the consolidated financial statements and related notes contained in the Company’s Annual Report on Form 10-K for the year ended December 31, 2016. The accounting policies used in preparing these consolidated financial statements are the same as those described in Note 1 to the consolidated financial statements in the Company’s Annual Report on Form 10-K for the year ended December 31, 2016. In the opinion of management, all adjustments (consisting of normal recurring adjustments) considered necessary for a fair statement of the results for interim periods have been included. All significant intercompany accounts and transactions have been eliminated in consolidation.

Accounts Receivable and Allowance for Doubtful Accounts

Accounts Receivable and Allowance for Doubtful Accounts – Trade accounts receivable are presented at face value, net of the allowance for doubtful accounts. The Company sells ethanol to gasoline refining and distribution companies, sells distillers grains and other feed co-products to dairy operators and animal feedlots and sells corn oil to poultry and biodiesel customers generally without requiring collateral.

The Company maintains an allowance for doubtful accounts for balances that appear to have specific collection issues. The collection process is based on the age of the invoice and requires attempted contacts with the customer at specified intervals. If, after a specified number of days, the Company has been unsuccessful in its collection efforts, a bad debt allowance is recorded for the balance in question. Delinquent accounts receivable are charged against the allowance for doubtful accounts once uncollectibility has been determined. The factors considered in reaching this determination are the apparent financial condition of the customer and the Company’s success in contacting and negotiating with the customer. If the financial condition of the Company’s customers were to deteriorate, resulting in an impairment of ability to make payments, additional allowances may be required.

Of the accounts receivable balance, approximately $57,237,000 and $64,853,000 at September 30, 2017 and December 31, 2016, respectively, were used as collateral under Kinergy’s operating line of credit. The allowance for doubtful accounts was $18,000 and $331,000 as of September 30, 2017 and December 31, 2016, respectively. The Company recorded a bad debt expense of $2,000 and $39,000 for the three months ended September 30, 2017 and 2016, respectively. The Company recorded a bad debt expense of $4,000 and $325,000 for the nine months ended September 30, 2017 and 2016, respectively. The Company does not have any off-balance sheet credit exposure related to its customers.

Provision for Income Taxes

Provision for Income Taxes – The Company recognized no tax benefit for the three and nine months ended September 30, 2017 due to the uncertainty of using its tax losses to offset future taxable income. The Company recognized a tax benefit of $0.2 million for the nine months ended September 30, 2016, as the Company has finalized certain of its tax returns. The Company applied a valuation allowance against the amount of deferred tax losses from the periods. To the extent the Company believes it can utilize these losses, it will adjust its provision (benefit) for income taxes accordingly in future periods.

Financial Instruments

Financial Instruments – The carrying values of cash and cash equivalents, accounts receivable, accounts payable, accrued liabilities and accrued PE Op Co. purchase are reasonable estimates of their fair values because of the short maturity of these items. The Company recorded its warrant liabilities at fair value. The Company believes the carrying value of its long-term debt approximates fair value because the interest rates on these instruments are variable, and are considered Level 2 fair value measurements.

Recent Accounting Pronouncements

Recent Accounting Pronouncements – In February 2016, the Financial Accounting Standards Board (“FASB”) issued new guidance on accounting for leases. Under the new guidance, lessees will be required to recognize the following for all leases (with the exception of short-term leases) at the commencement date: (1) a lease liability, which is a lessee’s obligation to make lease payments arising from a lease, measured on a discounted cash flow basis; and (2) a “right of use” asset, which is an asset that represents the lessee’s right to use the specified asset for the lease term. Under the new guidance, lessor accounting is largely unchanged, with some minor exceptions. Lessees will no longer be provided with a source of off-balance sheet financing for other than short-term leases. The standard is effective for public companies for annual reporting periods beginning after December 15, 2019, and for interim periods beginning after December 15, 2020. Early adoption is permitted. The Company has several operating leases that may be impacted by this guidance. The Company is currently evaluating the impact of the adoption of this accounting standard on its consolidated results of operations and financial condition.

In May 2014, the FASB issued new guidance (“ASC 606”) on the recognition of revenue. ASC 606 states that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The standard is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. In March and April 2016, the FASB issued further revenue recognition guidance amending principal vs. agent considerations regarding whether an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services.

The provisions of ASC 606 include a five-step process by which an entity will determine revenue recognition, depicting the transfer of goods or services to customers in amounts reflecting the payment to which an entity expects to be entitled in exchange for those goods or services. ASC 606 requires the Company to apply the following steps: (1) identify the contract with the customer; (2) identify the performance obligations in the contract; (3) determine the transaction price; (4) allocate the transaction price to the performance obligations in the contract; and (5) recognize revenue when, or as, the Company satisfies the performance obligation.

The Company will adopt ASC 606 on January 1, 2018. The Company is currently in the process of completing an evaluation of the new requirements, under ASC 606, on each of its major revenue types. The Company’s initial preliminary assessment indicates that ASC 606 will not materially change the way the Company accounts for its contracts with its customers, which will continue to be recognized at a point in time. The Company anticipates finalizing its assessment of the financial impact of ASC 606 during the fourth quarter of 2017 and anticipates adopting the new guidance using the modified retrospective transition method.

In April 2016, the FASB issued new guidance to reduce the complexity of certain aspects of accounting for employee share-based payment transactions. Prior to adoption of the standard, accruals of compensation costs were based on an estimated forfeiture rate. The new guidance allows an entity to make an entity-wide accounting policy election to either continue using an estimate of forfeitures or account for forfeitures only when they occur. The guidance is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. Effective January 1, 2017, the Company elected to discontinue the use of an estimated forfeiture rate and instead account for actual forfeitures as they occur. The transition guidance requires an adjustment to retained earnings for any cumulative effect. The impact to the Company upon adoption was determined to be immaterial.

Estimates and Assumptions

Estimates and Assumptions – The preparation of the consolidated financial statements in conformity with U.S. generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates are required as part of determining the fair value of warrants, allowance for doubtful accounts, net realizable value of inventory, estimated lives of property and equipment, long-lived asset impairments, valuation allowances on deferred income taxes and the potential outcome of future tax consequences of events recognized in the Company’s financial statements or tax returns, and the valuation of assets acquired and liabilities assumed as a result of business combinations. Actual results and outcomes may materially differ from management’s estimates and assumptions.

XML

2. Acquisition of ICP (Tables)

9 Months Ended

Sep. 30, 2017

Business Combinations [Abstract]

Schedule of acquired assets and liabilities

Cash and equivalents	$	1,079
Accounts receivable		11,636
Inventories		9,858
Other current assets		907
Total current assets		23,480
Property and equipment		60,497
Other assets		328
Total assets acquired	$	84,305
Accounts payable, trade	$	5,683
Other current liabilities		1,486
Total current liabilities		7,169
Other non-current liabilities		209
Total liabilities assumed	$	7,378
Net assets acquired	$	76,927
Estimated goodwill	$	–
Total purchase price	$	76,927

Schedule of statement of income

	Three Months Ended September 30,			Nine Months Ended September 30,
	2016			2017			2016
Revenues – pro forma	$	461,825		$	1,315,046		$	1,317,243
Net loss – pro forma	$	(3,302	)	$	(27,145	)	$	(10,110	)
Diluted net income (loss) per share – pro forma	$	(0.08	)	$	(0.64	)	$	(0.24	)
Diluted weighted-average shares – pro forma		42,226			42,358			42,156

XML

3. Segments (Tables)

9 Months Ended

Sep. 30, 2017

Segment Reporting [Abstract]

Schedule of Financial Data for Operating Segments

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Net Sales
Ethanol Production:
Net sales to external customers	$	304,812		$	266,299		$	804,012		$	767,171
Intersegment net sales		639			306			1,138			829
Total ethanol production net sales	$	305,451		$	266,605		$	805,150		$	768,000
Marketing and distribution:
Net sales to external customers	$	140,630		$	151,507		$	432,972		$	415,868
Intersegment net sales		2,334			2,018			6,135			5,861
Total marketing and distribution net sales		142,964			153,525			439,107			421,729
Intersegment eliminations		(2,973	)		(2,324	)		(7,273	)		(6,690	)
Net sales as reported	$	445,442		$	417,806		$	1,236,984		$	1,183,039

Cost of goods sold:
Ethanol production	$	292,743		$	262,964		$	797,277		$	759,210
Marketing and distribution		142,303			153,406			437,110			412,225
Intersegment eliminations		(1,669	)		(4,928	)		(5,348	)		(13,533	)
Cost of goods sold as reported	$	433,377		$	411,442		$	1,229,039		$	1,157,902

Income (loss) before provision for income taxes:
Ethanol production	$	2,638		$	(2,903	)	$	(15,981	)	$	(19,171	)
Marketing and distribution		(757	)		(1,524	)		(2,043	)		4,654
Corporate activities		(2,422	)		909			(5,940	)		2,614
	$	(541	)	$	(3,518	)	$	(23,964	)	$	(11,903	)
Depreciation and amortization:
Ethanol production	$	9,841		$	8,631		$	27,703		$	25,839
Marketing and distribution		–			–			–			3
Corporate activities		238			226			783			684
	$	10,079		$	8,857		$	28,486		$	26,526
Interest expense:
Ethanol production	$	1,850		$	3,521		$	4,061		$	15,600
Marketing and distribution		342			353			952			1,043
Corporate activities		1,634			–			4,144			–
	$	3,826		$	3,874		$	9,157		$	16,643

Schedule of Assets by Operating Segments

	September 30, 2017		December 31, 2016
Total assets:
Ethanol production	$	596,928	$	542,688
Marketing and distribution		129,294		146,356
Corporate assets		4,428		19,194
	$	730,650	$	708,238

XML

4. Inventories (Tables)

9 Months Ended

Sep. 30, 2017

Inventory Disclosure [Abstract]

Schedule of Inventories

	September 30, 2017		December 31, 2016
Finished goods	$	46,314	$	33,773
Work in progress		9,637		7,092
Raw materials		8,401		6,571
LCFS credits		5,892		10,926
Other		1,575		1,708
Total	$	71,819	$	60,070

XML

5. Derivatives (Tables)

9 Months Ended

Sep. 30, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Derivatives Not Designated as Hedging Instruments

	As of September 30, 2017
	Assets			Liabilities
Type of Instrument	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity contracts	Derivative instruments	$	3,017	Derivative instruments	$	2,755

	As of December 30, 2016
	Assets			Liabilities
Type of Instrument	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity contracts	Derivative instruments	$	978	Derivative instruments	$	4,115

Schedule of Recognized Gains (Losses) for Derivatives

	As of September 30, 2017
	Assets			Liabilities
Type of Instrument	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity contracts	Derivative instruments	$	3,017	Derivative instruments	$	2,755

	As of December 30, 2016
	Assets			Liabilities
Type of Instrument	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity contracts	Derivative instruments	$	978	Derivative instruments	$	4,115

The classification and amounts of the Company’s recognized gains (losses) for its derivatives not designated as hedging instruments are as follows (in thousands):

		Realized Gains (Losses)
		Three Months Ended September 30,
Type of Instrument	Statements of Operations Location	2017			2016
Commodity contracts	Cost of goods sold	$	(1,576	)	$	2,242

		Unrealized Gains (Losses)
		Three Months Ended September 30,
Type of Instrument	Statements of Operations Location	2017		2016
Commodity contracts	Cost of goods sold	$	1,093	$	(1,383	)

		Realized Gains (Losses)
		Nine Months Ended September 30,
Type of Instrument	Statements of Operations Location	2017			2016
Commodity contracts	Cost of goods sold	$	(4,495	)	$	2,152

		Unrealized Gains (Losses)
		Nine Months Ended September 30,
Type of Instrument	Statements of Operations Location	2017		2016
Commodity contracts	Cost of goods sold	$	3,659	$	(483	)

XML

6. Debt (Tables)

9 Months Ended

Sep. 30, 2017

Debt Disclosure [Abstract]

Schedule of Long Term Debt

	September 30, 2017			December 31, 2016
Kinergy line of credit	$	43,973		$	49,862
Pekin term loan		57,000			64,000
Pekin revolving loan		32,000			32,000
ICP term loan		24,000			–
ICP revolving loan		18,000			–
Pacific Aurora line of credit		–			1,000
Parent notes payable		68,948			55,000
		243,921			201,862
Less unamortized debt discount		(1,590	)		(1,626	)
Less unamortized debt financing costs		(2,027	)		(1,708	)
Less short-term portion		(20,000	)		(10,500	)
Long-term debt	$	220,304		$	188,028

XML

9. Pension and Retirement Benefit Plans(Tables)

9 Months Ended

Sep. 30, 2017

Retirement Plan [Member]

Defined contribution plan schedule

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Interest cost	$	98		$	172		$	293		$	516
Service cost		188			56			563			168
Expected return on plan assets		(169	)		(199	)		(506	)		(597	)
Net periodic expense	$	117		$	29		$	350		$	87

Postretirement Plan [Member]

Defined contribution plan schedule

	Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
Interest cost	$	21	$	35	$	63	$	105
Service cost		50		12		150		36
Amortization of (gain) loss		33		–		99		–
Net periodic expense	$	104	$	47	$	312	$	141

XML

10. Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2017

Fair Value Disclosures [Abstract]

Schedule of Significant Assumptions Used and Related Fair Values for Warrants

Original Issuance	Exercise Price	Volatility	Risk Free Interest Rate	Term (years)	Market Discount	Warrants Outstanding	Fair Value
07/3/2012	$6.09	40.9%	0.62%	0.50	11.3%	211,000	$651,000

Summary of Recurring Fair Value Measurements by Level

	Fair
	Value			Level 1			Level 2		Level 3
Assets:
Derivative instruments	$	3,017		$	3,017		$	–	$	–
	$	3,017		$	3,017		$	–	$	–
Liabilities:
Warrants	$	–		$	–		$	–	$	–
Derivative instruments		(2,755	)		(2,755	)		–		–
	$	(2,755	)	$	(2,755	)	$	–	$	–

Schedule of Fair Value of Level 3 Inputs to Warrants

Balance, December 31, 2016	$	651
Exercised warrants		(178	)
Adjustments to fair value for the period		(473	)
Balance, September 30, 2017	$	–

XML

11. Earnings Per Share (Tables)

9 Months Ended

Sep. 30, 2017

Earnings Per Share [Abstract]

Schedule of Computation of Basic and Diluted Earnings Per Share

	Three Months Ended September 30, 2017
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(202	)
Less: Preferred stock dividends		(319	)
Basic and diluted loss per share:
Loss available to common stockholders	$	(521	)		42,475	$	(0.01	)

	Three Months Ended September 30, 2016
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(3,518	)
Less: Preferred stock dividends		(319	)
Basic and diluted loss per share:
Loss available to common stockholders	$	(3,837	)		42,226	$	(0.09	)

	Nine Months Ended September 30, 2017
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(21,679	)
Less: Preferred stock dividends		(946	)
Basic and diluted loss per share:
Loss available to common stockholders	$	(22,625	)		42,358	$	(0.53	)

	Nine Months Ended September 30, 2016
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(11,658	)
Less: Preferred stock dividends		(949	)
Basic and diluted loss per share:
Loss available to common stockholders	$	(12,607	)		42,156	$	(0.30	)

XML

1. Organization and Basis of Presentation (Details Narrative) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Ethanol production capacity per year			605 million gallons per year
Ethanol market capacity per year			markets nearly 1.0 billion gallons of ethanol
Other products produced per year			produces over 2.5 million tons of co-products
Accounts receivable used as collateral	$ 57,237		$ 57,237		$ 64,853
Allowance for doubtful accounts	18		18		$ 331
Bad debt expense	2	$ 39	4	$ 325
Benefit for income taxes	$ 0	$ 0	$ 0	$ 245

XML

1. Organization and Basis of Presentation (Details Narrative 2)	Sep. 30, 2017 EthanolPlants
Pacific Aurora [Member]
Ownership interest	73.93%
ACEC [Member]
Noncontrolling interest owned	26.07%
ACEC [Member] | Pacific Aurora [Member]
Ownership interest	26.07%
Pacific Ethanol Central Plants [Member]
Number of ethanol plants	4

XML

2. Acquisition Of ICP (Details - Purchase allocation) - ICP [Member] $ in Thousands	Jun. 26, 2017 USD ($)
Cash and equivalents	$ 1,079
Accounts receivable	11,636
Inventories	9,858
Other current assets	907
Total current assets	23,480
Property and equipment	60,497
Other assets	328
Total assets acquired	84,305
Accounts payable, trade	5,683
Other current liabilities	1,486
Total current liabilities	7,169
Other non-current liabilities	209
Total liabilities assumed	7,378
Net assets acquired	76,927
Estimated goodwill	0
Total purchase price	$ 76,927

XML

2. Acquisition Of ICP (Details - Acquisition of Income) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2017	Sep. 30, 2016
Business Combinations [Abstract]
Revenues - pro forma	$ 461,825	$ 1,315,046	$ 1,317,243
Net loss - pro forma	$ (3,302)	$ (27,145)	$ (10,110)
Diluted net income (loss) per share – pro forma	$ (0.08)	$ (0.64)	$ (0.24)
Diluted weighted-average shares - pro forma	42,226	42,358	42,156

XML

2. Acquisition Of ICP (Details Narrative) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Jun. 26, 2017
Net Revenue	$ 445,442	$ 417,806	$ 1,236,984	$ 1,183,039
Pre-tax income	(541)	$ (3,518)	(23,964)	$ (11,903)
ICP [Member]
Accounts receivable					$ 11,636
Net Revenue	38,200		38,200
Pre-tax income	1,400		1,400
Selling, general and administrative expenses	$ 300		$ 300

XML

3. Segments - Schedule of Financial Date for Operating Segments (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Net Sales	$ 445,442	$ 417,806	$ 1,236,984	$ 1,183,039
Cost of goods sold	433,377	411,442	1,229,039	1,157,902
Income (loss) before provision for income taxes	(541)	(3,518)	(23,964)	(11,903)
Depreciation and amortization	10,079	8,857	28,486	26,526
Interest expense	3,826	3,874	9,157	16,643
Ethanol Production [Member]
Net Sales	305,451	266,605	805,150	768,000
Cost of goods sold	292,743	262,964	797,277	759,210
Income (loss) before provision for income taxes	2,638	(2,903)	(15,981)	(19,171)
Depreciation and amortization	9,841	8,631	27,703	25,839
Interest expense	1,850	3,521	4,061	15,600
Marketing and Distribution [Member]
Net Sales	142,964	153,525	439,107	421,729
Cost of goods sold	142,303	153,406	437,110	412,225
Income (loss) before provision for income taxes	(757)	(1,524)	(2,043)	4,654
Depreciation and amortization	0	0	0	3
Interest expense	342	353	952	1,043
Corporate Activities [Member]
Income (loss) before provision for income taxes	(2,422)	909	(5,940)	2,614
Depreciation and amortization	238	226	783	684
Interest expense	1,634	0	4,144	0
External Customers [Member] | Ethanol Production [Member]
Net Sales	304,812	266,299	804,012	767,171
External Customers [Member] | Marketing and Distribution [Member]
Net Sales	140,630	151,507	432,972	415,868
Intersegment Net Sales [Member] | Ethanol Production [Member]
Net Sales	639	306	1,138	829
Intersegment Net Sales [Member] | Marketing and Distribution [Member]
Net Sales	2,334	2,018	6,135	5,861
Intersubsegment Eliminations [Member]
Net Sales	(2,973)	(2,324)	(7,273)	(6,690)
Cost of goods sold	$ (1,669)	$ (4,928)	$ (5,348)	$ (13,533)

XML

3. Segments - Schedule of Assets by Operating Segments (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Assets	$ 730,650	$ 708,238
Ethanol Production [Member]
Assets	596,928	542,688
Marketing and Distribution [Member]
Assets	129,294	146,356
Corporate Assets [Member]
Assets	$ 4,428	$ 19,194

XML

3. Segments (Details Narrative)	9 Months Ended
	Sep. 30, 2017 Segments
Segment Reporting [Abstract]
Number of operating segments	2

XML

4. Inventories - Schedule of Inventories (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Inventory Disclosure [Abstract]
Finished goods	$ 46,314	$ 33,773
Work in progress	9,637	7,092
Raw materials	8,401	6,571
LCFS credits	5,892	10,926
Other	1,575	1,708
Total	$ 71,819	$ 60,070

XML

5. Derivatives - Schedule of Derivatives Not Designated as Hedging Instruments (Details) - Commodity Contracts [Member] - Non Designated Derivative Instruments [Member] - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Commodity contracts - Derivative assets	$ 3,017	$ 978
Commodity contracts - Derivative liabilities	$ 2,755	$ 4,115

XML

5. Derivatives - Schedule of Recognized Gains (Losses) for Derivatives (Details) - Commodity Contracts [Member] - Non Designated Derivative Instruments [Member] - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Derivative Instruments, Gain (Loss) [Line Items]
Realized Gains (Losses)	$ (1,576)	$ 2,242	$ (4,495)	$ 2,152
Unrealized Gains (Losses)	$ 1,093	$ (1,383)	$ 3,659	$ (483)

XML

5. Derivatives (Details Narrative) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Recognized gain on derivative instruments		$ 859		$ 1,669
Recognized loss on derivative instruments	$ (483)		$ (836)

XML

6. Debt - Schedule of Long Term Debt (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Long-term borrowings are summarized as follows
Notes payable	$ 68,948	$ 55,000
Total debt	243,921	201,862
Less unamortized discount	(1,590)	(1,626)
Less unamortized debt financing costs	(2,027)	(1,708)
Less short-term portion	(20,000)	(10,500)
Long-term debt	220,304	188,028
Kinergy [Member]
Long-term borrowings are summarized as follows
Line of credit/Revolving loan	43,973	49,862
Pekin [Member]
Long-term borrowings are summarized as follows
Line of credit/Revolving loan	32,000	32,000
Term loan	57,000	64,000
ICP [Member]
Long-term borrowings are summarized as follows
Line of credit/Revolving loan	18,000	0
Term loan	24,000	0
Pacific Aurora [Member]
Long-term borrowings are summarized as follows
Line of credit/Revolving loan	$ 0	$ 1,000

XML

6. Debt (Details Narrative) $ in Thousands	9 Months Ended
	Sep. 30, 2017 USD ($)
Asset unavailable for transfer due to loan restrictions	$ 305,660
Parent Notes Payable [Member]
Debt face value	13,948
Unamortized debt discount	418
Line of Credit [Member] | Kinergy [Member]
Line of credit maximum borrowing capacity	100,000
Line of credit remaining borrowing availability	22,410
Line of Credit [Member] | ICP Credit Agreement [Member] | Term Loan [Member]
Line of credit maximum borrowing capacity	24,000
Line of Credit [Member] | ICP Credit Agreement [Member] | Revolving Loan [Member]
Line of credit maximum borrowing capacity	$ 18,000
Maturity date	Sep. 01, 2022

XML

7. Warrants and stock options (Details Narrative) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Notes to Financial Statements
Stock issued from exercise of warrants and options			201,000
Proceeds from warrants and options exercised			$ 1,201
Warrants exercised	0	0		0
Options exercised	0	0		0
Warrant Outstanding	0		0

XML

8. Commitments and Contingencies (Details Narrative) $ in Thousands	9 Months Ended
	Sep. 30, 2017 USD ($)
Proceeds from legal settlement	$ 3,900
Gain on litigation settlement	$ 3,600
Ethanol Sales Contracts [Member]
Open ethanol indexed-price sales contracts	224,150,000 gallons
Open fixed-price sales contracts valued	$ 53,672
Co-products Sales Contracts [Member]
Open ethanol indexed-price sales contracts	16,000 tons
Open fixed-price sales contracts valued	$ 30,375
Ethanol Purchase Contracts [Member]
Indexed-price purchase contracts	20,050,000 gallons
Fixed-price purchase contracts value	$ 9,476
Ethanol Purchase Contracts [Member] | Suppliers [Member]
Fixed-price purchase contracts value	$ 11,000

XML

9. Pension and Retirement Benefit Plans (Details - Retirement Plans) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Retirement Plan [Member]
Interest cost	$ 98	$ 172	$ 293	$ 516
Service cost	188	56	563	168
Expected return on plan assets	(169)	(199)	(506)	(597)
Net periodic benefit cost	117	29	350	87
Postretirement Plan [Member]
Interest cost	21	35	63	105
Service cost	50	12	150	36
Amortization of (gain) loss	33	0	99	0
Net periodic benefit cost	$ 104	$ 47	$ 312	$ 141

XML

9. Pension Plans (Details Narrative) $ in Thousands	Dec. 31, 2016 USD ($)
Retirement Plan [Member]
Accumulated projected benefit obligation	$ 18,500
Fair value of plan assets	12,400
Underfunded amount	6,100
Postretirement Plan [Member]
Accumulated projected benefit obligation	$ 5,400

XML

10. Fair Value Measurements - Schedule of Significant Assumptions Used and Related Fair Values for Warrants (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2016	Sep. 30, 2017
Warrants Outstanding		0
Original issuance 7/3/2012 [Member]
Exercise price	$ 6.09
Volatility	40.90%
Risk free interest rate	0.62%
Term (years)	6 months
Market Discount	11.30%
Warrants Outstanding	211,000
Fair value	$ 651

XML

10. Fair Value Measurements (Details - Other derivatives) $ in Thousands	Sep. 30, 2017 USD ($)
Assets:
Assets	$ 3,017
Liabilities:
Liabilities	(2,755)
Derivative Financial Instrument [Member]
Assets:
Assets	3,017
Liabilities:
Liabilities	(2,755)
Warrants [Member]
Liabilities:
Liabilities	0
Level 1 [Member]
Assets:
Assets	3,017
Liabilities:
Liabilities	(2,755)
Level 1 [Member] | Derivative Financial Instrument [Member]
Assets:
Assets	3,017
Liabilities:
Liabilities	(2,755)
Level 1 [Member] | Warrants [Member]
Liabilities:
Liabilities	0
Level 2 [Member]
Assets:
Assets	0
Liabilities:
Liabilities	0
Level 2 [Member] | Derivative Financial Instrument [Member]
Assets:
Assets	0
Liabilities:
Liabilities	0
Level 2 [Member] | Warrants [Member]
Liabilities:
Liabilities	0
Level 3 [Member]
Assets:
Assets	0
Liabilities:
Liabilities	0
Level 3 [Member] | Derivative Financial Instrument [Member]
Assets:
Assets	0
Liabilities:
Liabilities	0
Level 3 [Member] | Warrants [Member]
Liabilities:
Liabilities	$ 0

XML

10. Fair Value Measurements - Schedule of Fair Value of Level 3 Inputs to Warrants (Details) - Level 3 [Member] - Warrants [Member] $ in Thousands	9 Months Ended
	Sep. 30, 2017 USD ($)
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	$ 651
Exercised warrants	(178)
Adjustments to fair value for the period	(473)
Ending Balance	$ 0

XML

11. Earnings Per Share - Schedule of Computation of Basic and Diluted Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Earnings Per Share [Abstract]
Net loss attributed to Pacific Ethanol, Inc.	$ (202)	$ (3,518)	$ (21,679)	$ (11,658)
Less: Preferred stock dividends	(319)	(319)	(946)	(949)
Income (loss) available to common stockholders	$ (521)	$ (3,837)	$ (22,625)	$ (12,607)
Weighted average number of shares outstanding, basic and diluted	42,475	42,226	42,358	42,156
Net loss per share, basic and diluted	$ (0.01)	$ (0.09)	$ (0.53)	$ (0.30)

XML

11. Earnings Per Share (Details Narrative) - shares	3 Months Ended	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2017
Earnings Per Share [Abstract]
Potentially dilutive weighted-average shares from convertible preferred stock outstanding	688,000	737,000