10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

(Mark One)

☒ ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the fiscal year ended December 31, 2017

OR

☐ 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

PACIFIC ETHANOL, INC.

(Exact name of registrant as specified in its charter)

Delaware	41-2170618
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

400 Capitol Mall, Suite 2060, Sacramento, California	95814
(Address of principal executive offices)	(Zip Code)

Registrant’s telephone number, including area code: (916) 403-2123

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

Title of Class	Name of Exchange on Which Registered
Common Stock, $0.001 par value	The Nasdaq Stock Market LLC (Nasdaq Capital Market)

Securities registered pursuant to Section 12(g) of the Act: None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes  ☐    No  ☒

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes  ☐    No  ☒

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  ☒    No  ☐

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 (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).  Yes  ☒    No  ☐

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. ☒

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

Large accelerated filer  ☐	Accelerated filer  ☒
Non-accelerated filer  ☐ (Do not check if a smaller reporting company)	Smaller reporting company  ☐
	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. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes  ☐    No  ☒

The aggregate market value of the voting and non-voting common equity held by nonaffiliates of the registrant computed by reference to the closing sale price of such stock, was approximately $266.3 million as of June 30, 2017, the last business day of the registrant’s most recently completed second fiscal quarter.

As of March 14, 2018, there were 43,959,245 shares of the registrant’s common stock, $0.001 par value per share, and 896 shares of the registrant’s non-voting common stock, $0.001 par value per share, outstanding.

DOCUMENTS INCORPORATED BY REFERENCE:

Part III incorporates by reference certain information from the registrant’s proxy statement (the “Proxy Statement”) for the 2018 Annual Meeting of Stockholders to be filed on or before April 30, 2018

TABLE OF CONTENTS

		Page
PART I
Item 1.	Business	1
Item 1A.	Risk Factors	14
Item 1B.	Unresolved Staff Comments	23
Item 2.	Properties	23
Item 3.	Legal Proceedings	23
Item 4.	Mine Safety Disclosures	24
PART II
Item 5.	Market For Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	25
Item 6.	Selected Financial Data	27
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	28
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	49
Item 8.	Financial Statements and Supplementary Data	50
Item 9.	Changes in and Disagreements With Accountants on Accounting and Financial Disclosure	50
Item 9A.	Controls and Procedures	50
Item 9B.	Other Information	52
PART III
Item 10.	Directors, Executive Officers and Corporate Governance	53
Item 11.	Executive Compensation	53
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	53
Item 13.	Certain Relationships and Related Transactions, and Director Independence	53
Item 14.	Principal Accounting Fees and Services	53
PART IV
Item 15.	Exhibits, Financial Statement Schedules	53
Index to Consolidated Financial Statements		F-1

CAUTIONARY STATEMENT

All statements included or incorporated by reference in this Annual Report on Form 10-K, other than statements or characterizations of historical fact, are forward-looking statements. Examples of forward-looking statements include, but are not limited to, statements concerning projected net sales, costs and expenses and gross margins; our accounting estimates, assumptions and judgments; the demand for ethanol and its co-products; the competitive nature of and anticipated growth in our industry; production capacity and goals; our ability to consummate acquisitions and integrate their operations successfully; and our prospective needs for additional capital. These forward-looking statements are based on our current expectations, estimates, approximations and projections about our industry and business, management’s beliefs, and certain assumptions made by us, all of which are subject to change. Forward-looking statements can often be identified by words such as “anticipates,” “expects,” “intends,” “plans,” “predicts,” “believes,” “seeks,” “estimates,” “may,” “will,” “should,” “would,” “could,” “potential,” “continue,” “ongoing,” similar expressions and variations or negatives of these words. These statements are not guarantees of future performance and are subject to risks, uncertainties and assumptions that are difficult to predict. Therefore, our actual results could differ materially and adversely from those expressed in any forward-looking statements as a result of various factors, some of which are listed under “Risk Factors” in Item 1A of this report. These forward-looking statements speak only as of the date of this report. We undertake no obligation to revise or update publicly any forward-looking statement for any reason, except as otherwise required by law.

PART I

Item 1. Business.

Business Overview

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

We 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 3.0 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 and high-quality alcohol products 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, or ACEC.

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

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We produce ethanol co-products at our production facilities such as wet distillers grains, or WDG, dry distillers grains with solubles, or 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.

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

Acquisition of Illinois Corn Processing LLC

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, 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 our 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 has integrated our 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 DDGS and ethanol. The acquisition was 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.

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Company History

We are a Delaware corporation formed in February 2005. Our common stock trades on The NASDAQ Capital Market under the symbol “PEIX.” Our Internet website address is http://www.pacificethanol.com. Information contained on our website is not part of this Annual Report on Form 10-K. Our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and any amendments to such reports filed with or furnished to the Securities and Exchange Commission and other Securities and Exchange Commission filings are available free of charge through our website as soon as reasonably practicable after the reports are electronically filed with, or furnished to, the Securities and Exchange Commission.

Business Strategy

Our primary goal is to advance our position and significantly increase our market share as a leading producer and marketer of low-carbon renewable fuels and high-quality alcohol products in the United States. The key elements of our business and growth strategy to achieve this objective include:

● Expand ethanol production capacity and distribution infrastructure. We believe the United States ethanol production industry is poised for continued consolidation. We evaluate and intend to pursue opportunities to acquire additional ethanol and specialty alcohol production, ethanol storage and distribution facilities, and related infrastructure as financial resources and business prospects make these acquisitions desirable. To this end, we are examining specific opportunities to extend our current production and marketing platform with strategic and synergistic acquisitions. In addition, we plan to expand our distribution infrastructure by increasing our ability to provide transportation, storage and related logistical services to our customers throughout the United States.

● Lower the carbon intensity of our ethanol. We plan to further reduce the carbon intensity of the ethanol we produce. We are able to sell this lower carbon intensity ethanol in certain regions at premium prices compared to higher carbon intensity ethanol. We are able to charge premium prices for this ethanol based on state laws and regulations, such as Low-Carbon Fuel Standards enacted in California and Oregon that require blenders to use lower carbon intensity ethanol in their gasoline. When available and cost-effective, we intend to use feedstock other than corn, including cellulosic feedstock, as the raw material used in the production of ethanol to further reduce the carbon intensity of our ethanol.

● Extend our marketing business into new regional and international markets. We have strengthened our market position in the Midwest through our acquisition in mid-2017 of ICP and through our acquisition in mid-2015 of Aventine Renewable Energy Holdings, Inc., now known as Pacific Ethanol Central, LLC, or PE Central. We intend to pursue opportunities to extend our marketing business into new regional markets within reach from our plants in Illinois and Nebraska. We also plan to continue to leverage our relationships with our customers to market and sell additional ethanol sourced from third parties. In addition, we are exploring opportunities to market and sell ethanol internationally.

● Implement new equipment and technologies. We intend to continue to evaluate and implement new equipment and technologies to increase our production and operating efficiencies, reduce our use of carbon-based fuels and improve our carbon scores, use diverse feedstocks, diversify products and revenues, including through our production of advanced biofuels, and improve our plant profitability as financial resources and market conditions justify these investments.

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Competitive Strengths

We believe that our competitive strengths include the following:

● Our customer and supplier relationships. We have extensive business relationships with customers and suppliers throughout the United States. In addition, we have developed extensive business relationships with major and independent un-branded gasoline suppliers who collectively control the majority of all gasoline sales in those regions.

● Our ethanol distribution network. We believe we have a competitive advantage due to our experience in marketing to customers in major metropolitan and rural markets in the United States. We have developed an ethanol distribution network for delivery of ethanol by truck to virtually every significant fuel terminal as well as to numerous smaller fuel terminals throughout California and other Western states. Fuel terminals have limited storage capacity and we have successfully secured storage tanks at many of the terminals we service. In addition, we have an extensive network of third-party delivery trucks available to deliver ethanol throughout the Western United States. In the Midwest, we have the ability to sell and deliver products in bulk via unit trains providing us access to Western, gulf coast and international markets. Further, higher value co-products from our Illinois facilities can be sold at premium prices under fixed price, longer-term contracts (up to 12 months) thus providing a more stable source of revenue in what can be a volatile commodity industry.

● Our strategic locations. We operate our ethanol plants in markets where we believe their individual locations, as well as our overall ethanol production and marketing platform, provide strategic advantages. Our production in both the Western United States and in the Midwest enables us to source ethanol from two different regions, which we believe allows us to address regional inefficiencies and other challenges such as rail congestion and other supply constraints, as well as pricing anomalies.

○ We operate four plants in the Western United States where we believe local characteristics create an opportunity to capture a significant production and shipping cost advantage over competing ethanol production facilities in other regions. We believe a combination of factors enables us to achieve this cost advantage, including:

■ Locations near fuel blending facilities lower our ethanol transportation costs while providing timing and logistical advantages over competing locations that require ethanol to be shipped over much longer distances, and in many cases require double-handling.

■ Locations adjacent to major rail lines allow the efficient delivery of corn in large unit trains from major corn-producing regions and allow for the efficient delivery of ethanol in large unit trains to other markets, including markets with higher demand.

■ Locations near large concentrations of dairy and/or beef cattle enable delivery of WDG, over short distances without the need for costly drying processes.

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○ We operate five plants in the Midwest which enables us to participate in the largest regional ethanol market in the United States as well as international markets. Our Midwest locations, coupled with our locations in the Western United States, also allow us many advantages over locations solely on the West Coast, including:

■ Locations in diverse markets assist us in spreading commodity and basis price risks across markets and products, supporting our efforts to optimize margin management.

■ Locations in the Midwest enhance our overall hedging opportunities with a greater correlation to the highly-liquid physical and paper markets in Chicago.

■ Locations in diverse markets support heightened flexibility and alternatives in feedstock procurement for our various production facilities.

■ Our Illinois facilities provide excellent logistical access via rail, truck and barge. The relatively unique wet milling process at one of our Illinois facilities allows us to extract the highest use and value from each component of the corn kernel. As a result, the wet milling process generates a higher level of cost recovery from corn than that produced at a dry mill.

■ Locations in the Midwest allow us deeper market insight and engagement in major ethanol and feed markets outside the Western United States, thereby improving pricing opportunities.

● Our low carbon-intensity ethanol. California and Oregon have enacted Low-Carbon Fuel Standards for transportation fuels. Under these Low-Carbon Fuel Standards, the ethanol we produce in the Western United States has a lower carbon-intensity than most ethanol produced at plants by other producers. This is primarily because our plants located on the West Coast use less energy in their production processes. The ethanol produced in California by other producers, all of which we market, also has a lower carbon-intensity rating than either gasoline or ethanol produced in the Midwest. The lower carbon-intensity rating of ethanol we produce at our plants located on the West Coast or otherwise resell from third-party California producers is valued in the market by our customers due to California’s Low Carbon Fuel Standard program, or LCFS, which has enabled us to capture premium prices for this ethanol.

● Modern technologies. Our plants use the latest production technologies to take advantage of state-of-the-art technical and operational efficiencies to achieve lower operating costs, higher yields and more efficient production of ethanol and its co-products and reduce our use of carbon-based fuels.

● Our experienced management. Our senior management team has a proven track record with significant operational and financial expertise and many years of experience in the ethanol, fuel and energy industries. Our senior executives, who average approximately 18 years of industry experience, have successfully navigated a wide variety of business and industry-specific challenges and deeply understand the business of successfully producing and marketing ethanol and its co-products.

We believe that these competitive strengths will help us attain our goal 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.

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Industry Overview and Market Opportunity

Overview of Ethanol Market

The primary applications for fuel-grade ethanol in the United States include:

● Octane enhancer. On average, regular unleaded gasoline has an octane rating of 87 and premium unleaded gasoline has an octane rating of 91. In contrast, pure ethanol has an average octane rating of 113. Adding ethanol to gasoline enables refiners to produce greater quantities of lower octane blend stock with an octane rating of less than 87 before blending. In addition, ethanol is commonly added to finished regular grade gasoline as a means of producing higher octane mid-grade and premium gasoline.

● Fuel blending. In addition to its performance and environmental benefits, ethanol is used to extend fuel supplies. In light of the need for transportation fuel in the United States and the dependence on foreign crude oil and refined products, the United States is increasingly seeking domestic sources of fuel. Much of the ethanol blending throughout the United States is done for the purpose of extending the volume of fuel sold at the gasoline pump.

● Renewable fuels. Ethanol is blended with gasoline to enable gasoline refiners to comply with a variety of governmental programs, in particular, the national Renewable Fuel Standard, or RFS, which was enacted to promote alternatives to fossil fuels. See “—Governmental Regulation.”

The United States ethanol industry is supported by federal and state legislation and regulation. For example, the Energy Independence and Security Act of 2007, which was signed into law in December 2007, significantly increased the prior RFS. Under the RFS, the mandated use of all renewable fuels rises incrementally in succeeding years and peaks at 36.0 billion gallons by 2022. Under the RFS, approximately 14.0 billion gallons in 2015, 14.5 billion gallons in 2016 and 15.0 billion gallons in 2017 were required from conventional, or corn-based, ethanol. Under the RFS, 15.0 billion gallons are required from conventional ethanol in 2018. The RFS allows the Environmental Protection Agency, or EPA, to adjust the annual requirement based on certain facts.

According to the Renewable Fuels Association, the domestic ethanol industry produced a record 15.8 billion gallons of ethanol in 2017. We believe that the ethanol market in California alone represented approximately 10% of the national market. However, the Western United States has relatively few ethanol facilities and local ethanol production levels are substantially below the local demand for ethanol. The balance of ethanol is shipped via rail from the Midwest to the Western United States. Gasoline and diesel fuel that supply the major fuel terminals are shipped in pipelines throughout portions of the Western United States. Unlike gasoline and diesel fuel, however, ethanol is not shipped in these types of pipelines because ethanol has an affinity for mixing with water already present in the pipelines. When mixed, water dilutes ethanol and creates significant quality control issues. Therefore, ethanol must be trucked from rail terminals to regional fuel terminals, or blending racks.

We believe that approximately 90% of the ethanol produced in the United States is made in the Midwest from corn. According to the Department of Energy, or DOE, ethanol is generally blended at a rate of 10% by volume, but is also blended at a rate of up to 85% by volume for vehicles designed to operate on 85% ethanol. The EPA has increased the allowable blend of ethanol in gasoline from 10% by volume to 15% by volume for model year 2001 and newer automobiles, pending final approvals by certain state regulatory authorities. Some retailers have begun blending at higher rates in states that have approved higher blend rates.

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Compared to gasoline, ethanol is generally considered to be cleaner burning and contains higher octane. We anticipate that the increasing demand for renewable transportation fuels coupled with limited opportunities for gasoline refinery expansions and the growing importance of reducing CO₂ emissions through the use of renewable fuels will generate additional growth in the demand for ethanol.

According to the DOE, total annual gasoline consumption in the United States is approximately 143 billion gallons and total annual ethanol consumption represented approximately 10% of this amount in 2017. The domestic ethanol industry has substantially reached this 10% blend ratio, and we believe the industry has significant potential for growth in the event the industry can migrate to an up to 15% blend ratio, which would translate into an annual demand of up to 20 billion gallons of ethanol.

Overview of Ethanol Production Process

Ethanol production from starch- or sugar-based feedstock is a highly-efficient process that we believe yields substantially more energy from ethanol and its co-products than is required to make the products. The modern production of ethanol requires large amounts of corn, or other high-starch grains, and water as well as chemicals, enzymes and yeast, and denaturants including unleaded gasoline or liquid natural gas, in addition to natural gas and electricity.

Dry Milling Process

In the dry milling process, corn or other high-starch grain is first ground into meal, then slurried with water to form a mash. Enzymes are then added to the mash to convert the starch into the simple sugar, dextrose. Ammonia is also added for acidic (pH) control and as a nutrient for the yeast. The mash is processed through a high temperature cooking procedure, which reduces bacteria levels prior to fermentation. The mash is then cooled and transferred to fermenters, where yeast is added and the conversion of sugar to ethanol and CO₂ begins.

After fermentation, the resulting “beer” is transferred to distillation, where the ethanol is separated from the residual “stillage.” The ethanol is concentrated to 190 proof using conventional distillation methods and then is dehydrated to approximately 200 proof, representing 100% alcohol levels, in a molecular sieve system. The resulting anhydrous ethanol is then blended with about 2.5% denaturant, which is usually gasoline, and is then ready for shipment to market.

The residual stillage is separated into a coarse grain portion and a liquid portion through a centrifugation process. The soluble liquid portion is concentrated to about 40% dissolved solids by an evaporation process. This intermediate state is called condensed distillers solubles, or syrup. The coarse grain and syrup portions are then mixed to produce WDG or can be mixed and dried to produce DDGS. Both WDG and DDGS are high-protein animal feed products.

Wet Milling Process

In the wet milling process, corn or other high-starch grain is first soaked or “steeped” in water for 24 – 48 hours to separate the grain into its many components. After steeping, the corn slurry is processed first to separate the corn germ, from which the corn oil can be further separated. The remaining fiber, gluten and starch components are further separated and sold.

The steeping liquor is concentrated in an evaporator. The concentrated product, called heavy steep water, is co-dried with the fiber component and is then sold as corn gluten feed. The gluten component is filtered and dried to produce corn gluten meal.

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The starch and any remaining water from the mash is then processed into ethanol or dried and processed into corn syrup. The fermentation process for ethanol at this stage is similar to the dry milling process.

Overview of Distillers Grains Market

Distillers grains are produced as a co-product of ethanol production and are valuable components of feed rations primarily to dairies and beef cattle markets, both nationally and internationally. Our plants produce both WDG and DDGS. WDG is sold to customers proximate to the plants and DDGS is delivered by truck, rail and barge to customers in domestic and international markets.

Producing WDG also allows us to use up to one-third less process energy, thus reducing production costs and lowering the carbon footprint of these plants, thereby increasing demand in California where premiums are paid for the low-carbon attributes.

Historically, the market price for distillers grains has generally tracked the value of corn. We believe that the market price of WDG and DDGS is determined by a number of factors, including the market value of corn, soybean meal and other competitive ingredients, the performance or value of WDG and DDGS in a particular feed formulation and general market forces of supply and demand, including export markets for these co-products. The market price of distillers grains is also often influenced by nutritional models that calculate the feed value of distillers grains by nutritional content, as well as reliability of consistent supply.

Customers

We market and sell through our wholly-owned subsidiary, Kinergy Marketing LLC, or Kinergy, all of the ethanol produced by our production facilities. Kinergy also markets 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 side. 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.

We also market all of the co-products produced at our plants. We do not market co-products from other ethanol producers. Our co-products include WDG, DDGS, wet and dry corn gluten feed, condensed distillers solubles, corn gluten meal, corn germ, corn oil, dried yeast and CO₂. 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.

Our production segment generated $838.3 million, $792.6 million and $527.7 million in net sales for the years ended December 31, 2017, 2016 and 2015, respectively, from the sale of ethanol. Our production segment generated $264.4 million, $253.2 million and $182.5 million in net sales for the years ended December 31, 2017, 2016 and 2015, respectively, from the sale of co-products.

During 2017, 2016 and 2015, our production segment sold an aggregate of approximately 527.2 million, 484.1 million and 319.2 million gallons of ethanol and 3.0 million, 2.8 million and 2.1 million tons of ethanol co-products, respectively.

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Our marketing segment generated $529.5 million, $579.0 million and $481.0 million in net sales for the years ended December 31, 2017, 2016 and 2015, respectively, from the sale of ethanol.

During 2017, 2016 and 2015, we produced or purchased ethanol from third parties and resold an aggregate of approximately 837 million, 816 million and 594 million gallons of fuel-grade ethanol and specialty alcohols to approximately 83, 81 and 69 customers, respectively. Sales to our three largest customers, Valero Energy Corporation, Chevron Products USA and Tesoro Refining and Marketing Company LLC in 2017, 2016 and 2015 represented an aggregate of approximately 33%, 35% and 39%, of our net sales, respectively. Sales to each of our other customers represented less than 10% of our net sales in each of 2017, 2016 and 2015.

Suppliers

Production Segment

Our production operations are dependent upon various raw materials suppliers, including suppliers of corn, natural gas, electricity and water. The cost of corn is the most important variable cost associated with our production. We source corn for our plants using standard contracts, including spot purchase, forward purchase and basis contracts. When resources are available, we seek to limit the exposure of our production operations to raw material price fluctuations by purchasing forward a portion of our corn requirements on a fixed price basis and by purchasing corn and other raw materials futures contracts.

During 2017, 2016 and 2015, purchases of corn from our four largest suppliers represented an aggregate of approximately 46%, 38% and 41% of our total corn purchases, respectively, for those periods. Purchases from each of our other corn suppliers represented less than 10% of total corn purchases in each of 2017, 2016 and 2015.

Marketing Segment

Our marketing operations are dependent upon various third-party producers of fuel-grade ethanol. In addition, we provide ethanol transportation, storage and delivery services through third-party service providers with whom we have contracted to receive ethanol at agreed upon locations from our third-party suppliers and to store and/or deliver the ethanol to agreed-upon locations on behalf of our customers. These contracts generally run from year-to-year, subject to termination by either party upon advance written notice before the end of the then current annual term.

During 2017, 2016 and 2015, we purchased and resold from third parties an aggregate of approximately 310 million, 334 million and 274 million gallons, respectively, of fuel-grade ethanol.

During 2017, 2016 and 2015, purchases of fuel-grade ethanol from our two largest third-party suppliers represented an aggregate of approximately 35%, 35% and 32% of our total third-party ethanol purchases, respectively, for those periods. Purchases from each of our other third-party ethanol suppliers represented less than 10% of total third-party ethanol purchases in each of 2017, 2016 and 2015.

Pacific Ethanol Plants

The table below provides an overview of our nine ethanol production facilities. Our plants have an aggregate annual production capacity of up to 605 million gallons. All of our plants are currently operational. As market conditions change, we may increase, decrease or idle production at one or more operational facilities or resume operations at any idled facility.

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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 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, an entity owned approximately 26% by ACEC.

	Madera Facility	Columbia Facility	Magic Valley Facility	Stockton Facility
Location	Madera, CA	Boardman, OR	Burley, ID	Stockton, CA
Approximate maximum annual ethanol production capacity (in millions of gallons)	40	40	60	60
Production milling process	Dry	Dry	Dry	Dry
Primary energy source	Natural Gas	Natural Gas	Natural Gas	Natural Gas
	Pekin Wet Facility	Pekin Dry Facility	Pekin ICP Facility	Aurora West Facility	Aurora East Facility
Location	Pekin, IL	Pekin, IL	Pekin, IL	Aurora, NE	Aurora, NE
Approximate maximum annual ethanol production capacity (in millions of gallons)	100	60	90	110	45
Production milling process	Wet	Dry	Dry	Dry	Dry
Primary energy source	Natural Gas	Natural Gas	Natural Gas	Natural Gas	Natural Gas

Commodity Risk Management

We employ various risk mitigation techniques. For example, we may seek to mitigate our exposure to commodity price fluctuations by purchasing forward a portion of our corn and natural gas requirements through fixed-price or variable-price contracts with our suppliers, as well as entering into derivative contracts for ethanol, corn and natural gas. To mitigate ethanol inventory price risks, we may sell a portion of our production forward under fixed- or index-price contracts, or both. We may hedge a portion of the price risks by selling exchange-traded futures contracts. Proper execution of these risk mitigation strategies can reduce the volatility of our gross profit margins. However, the market price of ethanol is volatile and subject to large fluctuations, and given the nature of our business, we cannot effectively hedge against extreme volatility or certain market conditions. For example, ethanol prices, as reported by the Chicago Board of Trade, or CBOT, ranged from $1.26 to $1.67 per gallon during 2017, from $1.31 to $1.75 per gallon during 2016 and from $1.31 to $1.69 per gallon during 2015; and corn prices, as reported by the CBOT, ranged from $3.30 to $3.92 per bushel during 2017, from $3.02 to $4.38 per bushel during 2016 and from $3.48 to $4.34 per bushel during 2015.

Marketing Arrangements

We market all the ethanol and specialty alcohols produced at our production facilities. In addition, we have exclusive ethanol marketing agreements with two third-party ethanol producers, Calgren Renewable Fuels, LLC and Aemetis Advanced Fuels Keyes, Inc., to market and sell their entire ethanol production volumes. Calgren Renewable Fuels, LLC owns and operates an ethanol production facility in Pixley, California with annual production capacity of 55 million gallons. Aemetis Advanced Fuels Keyes, Inc. owns and operates an ethanol production facility in Keyes, California with annual production capacity of 55 million gallons. We intend to evaluate and pursue opportunities to enter into marketing arrangements with other third-party ethanol producers as business prospects make these marketing arrangements advisable.

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Competition

We are the sixth largest producer of ethanol in the United States based on annualized volumes and operate in the highly competitive ethanol production and marketing industry. The largest ethanol producers in the United States are Archer-Daniels-Midland Company, POET, LLC, Green Plains Inc. and Valero Renewable Fuels Company, LLC, collectively with approximately 38% of the total installed ethanol production capacity in the United States. In addition, there are many mid-size producers with several plants under ownership, smaller producers with one or two plants, and several ethanol marketers that create significant competition. Overall, we believe there are over 200 ethanol production facilities in the United States with a total installed production capacity of approximately 16.2 billion gallons and many brokers and marketers with whom we compete for sales of ethanol and its co-products.

We believe that our competitive strengths include our customer and supplier relationships, our extensive ethanol distribution network, our strategic locations, our low carbon-intensity ethanol, our use of modern technologies at our production facilities and our experienced management. We believe that these advantages will help us to attain our goal 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.

Most of the largest metropolitan areas in the United States have fuel terminals served by rail, but other major metropolitan areas and more remote smaller cities and rural areas do not. We believe that we have a competitive advantage in the Western United States in particular due to our experience in marketing to the segment of customers located in major metropolitan and rural markets in the Western United States. We manage the complicated logistics of shipping ethanol to intermediate storage locations throughout the Western United States and trucking the ethanol from these storage locations to blending racks where the ethanol is blended with gasoline. We believe that by establishing an efficient service for truck deliveries to these more remote locations, we have differentiated ourselves from our competitors on the West Coast. In addition, due to our plant locations on the West Coast, we believe that we benefit from our ability to increase spot sales of ethanol from those plants following ethanol price spikes caused from time to time by rail delays in delivering ethanol from the Midwest to the Western United States.

Our strategic locations in the Western United States designed to capitalize on cost efficiencies may nevertheless result in higher than expected costs as a result of more expensive raw materials and related shipping costs, including corn, which generally must be transported from the Midwest. If the costs of producing and shipping ethanol and its co-products over short distances are not advantageous relative to the costs of obtaining raw materials from the Midwest, then the benefits of our strategic locations on the West Coast may not be realized.

Governmental Regulation

Our business is subject to federal, state and local laws and regulations relating to the production of renewable fuels, the protection of the environment and in support of the corn and ethanol industries. These laws, their underlying regulatory requirements and their enforcement, some of which are described below, impact, or may impact, our existing and proposed business operations by imposing:

● restrictions on our existing and proposed business operations and/or the need to install enhanced or additional controls;

● the need to obtain and comply with permits and authorizations;

● liability for exceeding applicable permit limits or legal requirements, in some cases for the remediation of contaminated soil and groundwater at our facilities, contiguous and adjacent properties and other properties owned and/or operated by third parties; and

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● specifications for the ethanol we market and produce.

In addition, some governmental regulations are helpful to our ethanol production and marketing business. The ethanol fuel industry is supported by federal and state mandates and environmental regulations that favor the use of ethanol in motor fuel blends in North America. Some of the governmental regulations applicable to our ethanol production and marketing business are briefly described below.

National Energy Legislation

The Energy Independence and Security Act of 2007, which was signed into law in December 2007, significantly increased the prior RFS. The RFS significantly increases the mandated use of renewable fuels, rising incrementally each year, to 36.0 billion gallons by 2022.

Under the provisions of the Energy Independence and Security Act of 2007, the EPA has the authority to waive the mandated RFS requirements in whole or in part. To grant a waiver, the EPA administrator must determine, in consultation with the Secretaries of Agriculture and Energy, that there is inadequate domestic renewable fuel supply or implementation of the requirement would severely harm the economy or environment of a state, region or the United States as a whole.

Legislation aimed at reducing or eliminating the renewable fuel use required by the RFS has been introduced since the 115^th United States Congress began on January 3, 2017. 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 referred to a congressional subcommittee, which will consider them before possibly sending any of them on to the House of Representatives as a whole. No legislation affecting the RFS or ethanol has been introduced in the Senate so far this session.

E15 (a Blend of Gasoline and Ethanol)

The EPA has allowed fuel and fuel-additive manufacturers to introduce into commercial gasoline that contains greater than 10% ethanol by volume, up to 15% ethanol by volume, or E15, for vehicles from model year 2001 and beyond. Additional changes to some states’ laws to allow for the use of E15 are still required; however, commercial sale of E15 has begun in some states. At the end of 2017, there were over 1,200 stations offering E15. We anticipate the number of stations offering E15 fuel will reach over 2,000 in 2018.

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State Energy Legislation and Regulations

In January 2007, California’s Governor signed an executive order directing the California Air Resources Board to implement California’s LCFS for transportation fuels. California’s LCFS requires fuel suppliers to reduce the carbon intensity of transportation fuels to 10% below 2010 levels by 2020. The Governor’s office estimates that the standard will have the effect of increasing current renewable fuels use in California by three to five times by 2020.

The California Air Resources Board has engaged in a comprehensive process to consider extending California’s LCFS through 2030, applying aggressive new carbon intensity reduction targets for the final 10 years. We believe the revised program will be beneficial as we produce among the lowest carbon intensity ethanol commercially available, and we receive a premium for the fuel we sell into the California marketplace, which we expect will increase as the compliance curve steepens, which began in 2016.

A program similar to California’s LCFS has also been adopted in Oregon and the Canadian province of British Columbia, and is under discussion in Washington State. These regions, together with California, represent a very large segment of the overall demand for transportation fuels in the United States.

Additional Environmental Regulations

In addition to the governmental regulations applicable to the ethanol production and marketing industry described above, our business is subject to additional federal, state and local environmental regulations, including regulations established by the EPA, the San Joaquin Valley Regional Water Quality Control Board, the San Joaquin Valley Air Pollution Control District and the California Air Resources Board. We cannot predict the manner or extent to which these regulations will harm or help our business or the ethanol production and marketing industry in general.

Employees

As of March 15, 2018, we had approximately 560 full-time employees. We believe that our employees are highly-skilled, and our success will depend in part upon our ability to retain our employees and attract new qualified employees, many of whom are in great demand. Approximately 180 of our employees are presently represented by a labor union and covered by a collective bargaining agreement. We have never had a work stoppage or strike and we consider our relations with our employees to be good.

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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 years ended December 31, 2017 and 2015, we incurred consolidated net losses of approximately $38.1 million and $18.9 million, respectively. For the year ended December 31, 2015, we incurred negative operating cash flows of $28.0 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.

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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. 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 16.2 billion gallons in 2017. 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 supply of ethanol may not be commensurate with increases in the demand for 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 $1.26 to $1.67 per gallon during 2017, $1.31 to $1.75 per gallon during 2016 and $1.31 to $1.69 per gallon during 2015. 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.

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Disruptions in 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 and specialty alcohols 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 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 products 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.

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

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. In addition, our open contract positions may require cash deposits to cover margin calls, negatively impacting our liquidity. As a result, our results of operations and financial condition may be adversely affected by our hedging activities and 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, specialty alcohols and 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.

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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.

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

Our business following recent acquisitions is larger than the individual businesses of Pacific Ethanol and the acquired companies prior to the acquisitions. Our future success depends, in part, upon our ability to manage our expanded business, which may pose continued 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 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;

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● 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.

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 business 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 price of ethanol relative to the price of gasoline, 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.

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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 referred 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.

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, POET, LLC, Green Plains, Inc. and Valero Renewable Fuels Company, LLC, 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.

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As of December 31, 2017, of our $154.6 million of federal NOLs, we had $94.9 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.

Our business is not diversified. Our sales are highly concentrated within the ethanol production and marketing industry. We expect to be substantially focused on the production and marketing of ethanol and its co-products for the foreseeable future. An industry shift away from ethanol, or the emergence of new competing products, may significantly reduce the demand for ethanol. However, we may be unable to timely alter our business focus away from the production and marketing of ethanol to other renewable fuels or competing products. 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.

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.

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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, 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. 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 2017, 2016 and 2015, three customers accounted for an aggregate of approximately $544 million, $572 million and $467 million in net sales, representing 33%, 35% and 39% 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.

We incur significant expenses to maintain and upgrade our operating equipment and plants, and any interruption in the operation of our facilities may harm our operating performance.

We regularly incur significant expenses to maintain and upgrade our equipment and facilities. The machines and equipment we use to produce our products are complex, have many parts and some are run on a continuous basis. We must perform routine maintenance on our equipment and will have to periodically replace a variety of parts such as motors, pumps, pipes and electrical parts. In addition, our facilities require periodic shutdowns to perform major maintenance and upgrades. These scheduled facility shutdowns result in decreased sales and increased costs in the periods in which a shutdown occurs and could result in unexpected operational issues in future periods as a result of changes to equipment and operational and mechanical processes made during the shutdown period.

 -21-

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 ramifications of these risks are greater in magnitude 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 December 31, 2017, we had approximately $302.9 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;

● 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.

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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.

Item 1B. Unresolved Staff Comments.

We have received no written comments regarding our periodic or current reports from the staff of the Securities and Exchange Commission that were issued 180 days or more preceding the end of our 2017 fiscal year and that remain unresolved.

Item 2. Properties.

Our corporate headquarters, located in Sacramento, California, consists of a 10,000 square foot office under a lease expiring in 2018. We have plants located in Madera, California, at a 137 acre facility; Boardman, Oregon, at a 25 acre facility; Burley, Idaho, at a 160 acre facility; and Stockton, California, at a 30 acre facility. We own the land in Madera, California and Burley, Idaho. The land in Boardman, Oregon and Stockton, California are leased under leases expiring in 2026 and 2022, respectively. We also have plants located in Pekin, Illinois at facilities totaling 145 acres and Aurora, Nebraska, at a 96 acre facility. We own the land in Pekin, Illinois and Aurora, Nebraska, as well as the grain handling facility, loop track and the real property on which they are located in Aurora, Nebraska. We also own an idled ethanol production facility in Canton, Illinois on a 289 acre facility, of which a significant portion is farm land. Our production segment includes ethanol production facilities. See “Business—Pacific Ethanol Plants.”

Item 3. 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.

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People of the State of Illinois v. Pacific Ethanol Pekin, LLC, case no. 18-CH-06, was filed on January 8, 2018 in the Circuit Court for the 10th Judicial Circuit in Tazewell County, Illinois. The Illinois Attorney General, on behalf of the People of the State of Illinois, alleges violations of the Pekin facility’s NPDES permit and water pollution associated with the facility’s discharge. Most of the alleged violations relate to thermal limits set forth in the permit. The complaint seeks a cease and desist order and damages for the alleged violations in accordance with statutory limits under the Illinois Environmental Protection Act. We are currently in negotiations with the Illinois Attorney General seeking to resolve this matter.

Item 4. Mine Safety Disclosures.

Not applicable.

 -24-

PART II

Item 5. Market For Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.

Market Information

Our common stock trades on The NASDAQ Capital Market under the symbol “PEIX”. We also have non-voting common stock outstanding which is not listed on an exchange. The table below shows, for each fiscal quarter indicated, the high and low sales prices of shares of our common stock. The prices shown reflect inter-dealer prices, without retail mark-up, mark-down or commission, and may not necessarily represent actual transactions.

	Price Range
	High		Low
Year Ended December 31, 2017:
First Quarter (January 1 – March 31)	$	10.05	$	6.50
Second Quarter (April 1 – June 30)	$	7.45	$	5.63
Third Quarter (July 1 – September 30)	$	7.50	$	4.15
Fourth Quarter (October 1 – December 31)	$	6.00	$	4.10
Year Ended December 31, 2016:
First Quarter	$	5.85	$	2.41
Second Quarter	$	6.76	$	3.67
Third Quarter	$	7.50	$	5.37
Fourth Quarter	$	10.95	$	5.75

Security Holders

As of March 14, 2018, we had 43,959,245 shares of common stock outstanding held of record by approximately 230 stockholders and 896 shares of non-voting common stock outstanding held of record by one stockholder. These holders of record include depositories that hold shares of stock for brokerage firms which, in turn, hold shares of stock for numerous beneficial owners. On March 14, 2018, the closing sales price of our common stock on The NASDAQ Capital Market was $3.63 per share.

Performance Graph

The graph below shows a comparison of the cumulative total stockholder return on our common stock with the cumulative total return on The NASDAQ Composite Index and The NASDAQ Clean Edge Green Energy Index, or Peer Group, in each case over the five-year period ended December 31, 2017.

The graph assumes $100 invested at the indicated starting date in our common stock and in each of The NASDAQ Composite Index and the Peer Group, with the reinvestment of all dividends. We have not paid or declared any cash dividends on our common stock and do not anticipate paying any cash dividends on our common stock in the foreseeable future. Stockholder returns over the indicated periods should not be considered indicative of future stock prices or stockholder returns. This graph assumes that the value of the investment in our common stock and each of the comparison groups was $100 on December 31, 2012.

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	Cumulative Total Return ($)
	12/12	12/13	12/14	12/15	12/16	12/17
PACIFIC ETHANOL, INC.	100.00	107.35	217.86	100.81	200.36	95.96
THE NASDAQ COMPOSITE INDEX	100.00	141.63	162.09	173.33	187.19	242.29
THE NASDAQ CLEAN EDGE GREEN ENERGY INDEX	100.00	196.27	208.69	232.98	222.42	295.91

Dividend Policy

We have never paid cash dividends on our common stock and do not intend to pay cash dividends on our common stock in the foreseeable future. We anticipate that we will retain any earnings for use in the continued development of our business.

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. Further, the holders of our outstanding Series B Preferred Stock are entitled to dividends of 7% per annum, payable quarterly in arrears. In 2017, 2016 and 2015, we declared and paid in cash dividends on our outstanding shares of Series B Preferred Stock as they became due. Accrued and unpaid dividends in respect of our Series B Preferred Stock must be paid prior to the payment of any dividends in respect of shares of our common stock.

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Recent Sales of Unregistered Securities

None.

Purchases of Equity Securities by the Issuer and Affiliated Purchasers

None.

Item 6. Selected Financial Data.

The following table sets forth our selected consolidated financial data. We prepared this information using our consolidated financial statements for each of the years ended December 31, 2017, 2016, 2015, 2014 and 2013.

You should read this selected consolidated financial data together with the consolidated financial statements and related notes contained in this report and in our prior and subsequent reports filed with the Securities and Exchange Commission, as well as the section of this report and our other reports entitled “Management’s Discussion and Analysis of Financial Condition and Results of Operations.” The historical results that appear below are not necessarily indicative of results to be expected for any future periods.

	Years Ended December 31,
	2017			2016			2015			2014			2013
	(in thousands, except per share data)
Consolidated Statements of Operations Data:
Net sales	$	1,632,255		$	1,624,758		$	1,191,176		$	1,107,412		$	908,437
Cost of goods sold (1)		1,626,324			1,570,400			1,180,810			995,695			872,370
Gross profit		5,931			54,358			10,366			111,717			36,067
Selling, general and administrative expenses (1)		31,516			30,849			26,368			20,340			17,158
Asset impairment		—			—			1,970			—			—
Income (loss) from operations		(25,585	)		23,509			(17,972	)		91,377			18,909
Fair value adjustments and warrant inducements		473			(557	)		1,641			(37,532	)		(1,013	)
Interest expense		(12,938	)		(22,406	)		(12,594	)		(9,438	)		(15,671	)
Loss on extinguishments of debt		—			—			—			(2,363	)		(3,035	)
Other income (expense), net		(345	)		(1	)		18			(905	)		(352	)
Income (loss) before provision for income taxes		(38,395	)		545			(28,907	)		41,139			(1,162	)
Provision (benefit) for income taxes		(321	)		(981	)		(10,034	)		15,137			—
Consolidated net income (loss)		(38,074	)		1,526			(18,873	)		26,002			(1,162	)
Net (income) loss attributed to noncontrolling interests		3,110			(107	)		87			(4,713	)		381
Net income (loss) attributed to Pacific Ethanol, Inc.	$	(34,964	)	$	1,419		$	(18,786	)	$	21,289		$	(781	)
Preferred stock dividends		(1,265	)		(1,269	)		(1,265	)		(1,265	)		(1,265	)
Income allocated to participating securities		—			(2	)		—			(585	)		—
Income (loss) available to common stockholders	$	(36,229	)	$	148		$	(20,051	)	$	19,439		$	(2,046	)
Income (loss) per share, basic	$	(0.85	)	$	0.00		$	(0.60	)	$	0.93		$	(0.17	)
Income (loss) per share, diluted	$	(0.85	)	$	0.00		$	(0.60	)	$	0.86		$	(0.17	)
Weighted-average shares outstanding, basic		42,745			42,182			33,173			20,810			12,264
Weighted-average shares outstanding, diluted		42,745			42,251			33,173			22,669			12,264

Consolidated Balance Sheet Data:
Cash and cash equivalents	$	49,489	$	64,259	$	52,712	$	62,084	$	5,151
Working capital	$	112,540	$	156,360	$	125,033	$	112,498	$	51,161
Total assets	$	720,296	$	708,238	$	674,680	$	297,540	$	239,986
Long-term debt, net of current portion	$	221,091	$	188,028	$	203,861	$	34,177	$	98,095
Stockholders’ equity	$	383,700	$	418,261	$	371,544	$	217,982	$	94,901

(1) Reflects reclassification of co-product selling costs from cost of goods sold to selling, general and administrative expenses of approximately $2.5 million, $3.0 million, $3.2 million and $3.1 million for the years ended December 31, 2016, 2015, 2014 and 2013, respectively, to reflect current year classification.

No cash dividends on our common stock were declared during any of the periods presented above.

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Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

The following discussion and analysis of our financial condition and results of operations should be read in conjunction with our consolidated financial statements and notes to consolidated financial statements included elsewhere in this report. This discussion contains forward-looking statements, reflecting our plans and objectives that involve risks and uncertainties. Actual results and the timing of events may differ materially from those contained in these forward-looking statements due to a number of factors, including those discussed in the section entitled “Risk Factors” and elsewhere in this report.

Overview

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

We 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 3.0 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 and high-quality alcohol products 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, or ACEC.

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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, dried distillers grains with solubles, or 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.

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

Current Initiatives and Outlook

Our results for the fourth quarter and full year reflect a difficult production margin environment due to lower average ethanol sales prices throughout the year. The industry’s high inventory levels negatively impacted ethanol sales prices, compressing production margins despite a decline in our average delivered cost of corn. Our results also reflect increased production gallons sold in the second half of the year predominately from increased volumes from our recently acquired ICP facility which, for the second half of the year, performed well and contributed $75.9 million in net sales and $3.7 million in pre-tax income.

In response to high industry-wide inventory levels and lower margins, we moderated production in locations most impacted by margin compression and where we were not otherwise contractually committed. We also reduced sales of third party ethanol to focus our sales efforts around our own production volumes where we are best able to maximize profitability and contribute to greater pricing stability. Industry inventory levels have since declined resulting from lower production and higher domestic and export demand. Ethanol inventories, which reached a record high at the beginning of 2018—running twenty percent higher than the same period in 2017—are now slightly lower than the same period last year while ethanol demand remains strong. As a result, margins have improved by approximately fifteen cents per gallon from the lows in December.

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We remain confident we are heading into a stronger year supported by an improved supply and demand balance, continued stability in corn prices, a strong export market and increasing adoption of E15 across the United States. Domestic gasoline demand for the first two months of 2018 is more than 5% higher than in the comparable period in 2017. Exports reached a record level of 1.37 billion gallons in 2017, a 17% increase over 2016, and we expect similar if not greater export growth in 2018. We also expect growth in E15 availability and sales. At the beginning of 2018, E15 was available at more than 1,200 stations across 29 states. We expect E15 availability at over 2,000 stations by year end. We continue to work diligently with the industry to enable E15 and higher blends to achieve Reid Vapor Pressure (RVP) parity with the standard 10% blend ratio which will allow E15 sales for the entire year across the United States and further bolster ethanol demand. Ethanol remains a low cost, low carbon, high octane transportation fuel that we believe will continue to attract additional demand.

We continue to focus on transactions and initiatives to build long-term value. As a leading innovator in the ethanol industry, we are focused on making appropriate investments in our production facilities to reduce costs, improve our carbon score and support profitable operations. Our acquisition of ICP in July provided product diversification, bringing us high-quality alcohol products, which help support stronger margins and reduce our exposure to commodity price fluctuations in the fuel ethanol market. Our integration of ICP is progressing well and we are on track to achieve our goal of $4.5 million in annualized cost synergies in 2018.

Our 3.5 megawatt cogeneration system at our Stockton plant is partially complete. The first natural gas fired cogeneration unit is now fully commissioned, generating power and used in production at the plant. The second of two cogeneration units is still in its commissioning stage. The system converts process waste gas and natural gas into electricity and steam, reducing energy costs by up to $4.0 million per year and lowering carbon and nitrogen oxide emissions.

We received an updated LCFS pathway from the California Air Resources Board, incorporating the benefits of our industrial scale membrane system at our Madera facility that separates water from ethanol during the plant’s dehydration process. 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. We are in the process of evaluating this technology for potential implementation at other plants.

We are producing commercial levels of cellulosic ethanol at our Stockton, Madera and Magic Valley plants and generating D3 RINs at our Stockton plant. We have filed for approval from the EPA to produce D3 RINs at our Madera and Magic Valley plants.

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

Our capital expenditures for 2017 totaled $20.9 million. We expect our 2018 capital expenditures to approximate our 2017 expenditure level, although we may adjust this amount based on industry economics and our financial performance.

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We plan to drive growth by leveraging 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. The foundations of this strategy are our strategically located bio-refineries, which enable us to serve multiple markets; the diversity of our production, geography, technology, feedstocks and logistics, which helps us mitigate exposure to commodity price risks within fuel markets; and our focus on evaluating and investing in plant improvement and other initiatives to increase production and operating efficiencies and yields.

2017 Financial Performance Summary

Summary

Our consolidated net sales remained consistent at $1.6 billion compared to 2016. Our net income (loss) available to common stockholders declined by $36.3 million from net income of $0.1 million for 2016 to a net loss of $36.2 million for 2017.

Factors that contributed to our results of operations for 2017 include:

● Net sales. Our net sales for the period remained consistent, the result of an increase in total gallons sold, offset by a decrease in our average sales price per gallon. Our total gallons of ethanol sold increased 3% to 952 million gallons for 2017 from 925 million gallons for 2016. Our production sales volume of ethanol increased 9% to 527 million gallons for 2017 from 484 million gallons for 2016, partially offset by a decrease in our third-party sales volume of 4% to 425 million gallons for 2017 from 440 million gallons for 2016. The increased production sales volume was primarily due to our mid-year acquisition of Illinois Corn Processing, LLC, or ICP. Our decreased third party sales volume was primarily due to an intentional reduction in less profitable third party sales.

● Gross margin. Our gross margin decreased to 0.4% for 2017 from 3.3% for 2016. The decline in our gross margin was primarily the result of lower corn crush margins compared to 2016, predominately due to lower average ethanol sales prices.

● Selling, general and administrative expenses. Our selling, general and administrative expenses, or SG&A, increased by $0.7 million to $31.5 million for 2017, as compared to $30.8 million for 2016, primarily as a result of higher employee benefits, non-cash compensation and professional fees related to our acquisition of ICP, and higher overhead and other costs related to ICP’s business. These increased expenses were partially offset by $3.6 million in gains associated with legal matters resolved in the first quarter of 2017.

● Interest expense. Our interest expense declined by $9.5 million to $12.9 million for 2017 from $22.4 million for 2016. This decline primarily resulted from our refinance of debt balances acquired in connection with our acquisition of our Midwest plants, in which we replaced existing debt with lower cost debt.

Sales and Margins

We generate sales by marketing all the ethanol produced by our ethanol plants, all the ethanol produced by two other ethanol producers in the Western United States and ethanol purchased from other third-party suppliers throughout the United States. We also market high-quality alcohol products and ethanol co-products, including WDG and DDGS, wet and dry corn gluten feed, condensed distillers solubles, corn gluten meal, corn germ, corn oil, dried yeast and CO₂, for our ethanol plants.

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Our profitability is highly dependent on various commodity prices, including the market prices of ethanol, corn and natural gas.

Our average ethanol sales price declined by 3% to $1.62 per gallon for 2017 compared to $1.67 per gallon for 2016. The average price of ethanol as reported by the Chicago Board of Options Trade, or CBOT, declined by less than 1% to $1.50 per gallon for 2017 compared to $1.51 per gallon for 2016. Our average cost of corn declined by 2% to $3.82 per bushel for 2017 from $3.90 per bushel for 2016. The average price of corn as reported by the CBOT increased slightly to $3.59 per bushel for 2017 from $3.58 per bushel for 2016.

We have three principal methods of selling ethanol: as a merchant, as a producer and as an agent. See “—Critical Accounting Policies—Revenue Recognition” below.

When acting as a merchant or as a producer, we generally enter into sales contracts to ship ethanol to a customer’s desired location. We support these sales contracts through purchase contracts with several third-party suppliers or through our own production. We manage the necessary logistics to deliver ethanol to our customers either directly from a third-party supplier or from our inventory via truck or rail. Our sales as a merchant or as a producer expose us to significant price risks resulting from potential fluctuations in the market price of ethanol and corn. Our exposure varies depending on the magnitude of our sales and purchase commitments compared to the magnitude of our existing inventory, as well as the pricing terms—such as market index or fixed pricing—of our contracts. We seek to mitigate our exposure to price risks by implementing appropriate risk management strategies.

When acting as an agent for third-party suppliers, we conduct back-to-back purchases and sales in which we match ethanol purchase and sale contracts of like quantities and delivery periods. When acting in this capacity, we receive a predetermined service fee and have little or no exposure to price risks resulting from potential fluctuations in the market price of ethanol. For these sales, we record the marketing fee as net sales.

We believe that our gross profit margins depend primarily on five key factors:

● the market price of ethanol, which we believe is impacted by the degree of competition in the ethanol market; the price of gasoline and related petroleum products; and government regulation, including government mandates;

● the market price of key production input commodities, including corn and natural gas;

● the market price of co-products;

● our ability to anticipate trends in the market price of ethanol, co-products, and key input commodities and implement appropriate risk management and opportunistic strategies; and

● the proportion of our sales of ethanol produced at our ethanol plants to our sales of ethanol produced by unrelated third-parties.

We seek to optimize our gross profit margins by anticipating the factors above and, when resources are available, implementing hedging transactions and taking other actions designed to limit risk and address these factors. For example, we may seek to decrease inventory levels in anticipation of declining ethanol prices and increase inventory levels in anticipation of rising ethanol prices. We may also seek to alter our proportion or timing, or both, of purchase and sales commitments. Furthermore, we may diversify our ethanol feedstock to lower our average costs and/or increase our ethanol sales prices from premiums for low-carbon intensity rated ethanol.

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Our limited resources to act upon the anticipated factors described above and/or our inability to anticipate these factors or their relative importance, and adverse movements in the factors themselves, could result in declining or even negative gross profit margins over certain periods of time. Our ability to anticipate these factors or favorable movements in these factors may enable us to generate above-average gross profit margins. However, given the difficulty associated with successfully forecasting any of these factors, we are unable to estimate our future gross profit margins.

Results of Operations

Accounting for the Results of Illinois Corn Processing, LLC

We closed our acquisition of ICP on July 3, 2017 and, as a result, our results of operations include ICP’s results of operations only for the period from July 3, 2017 through December 31, 2017.

Selected Financial Information

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:

	Years Ended December 31,									Percentage Change
	2017			2016			2015			2017 vs 2016			2016 vs 2015
Production gallons sold (in millions)		527.2			484.1			319.2			8.9	%		51.7	%
Third-party gallons sold (in millions)		424.8			440.4			382.3			(3.5	)%		15.2	%
Total gallons sold (in millions)		952.0			924.5			701.5			3.0	%		31.8	%
Production capacity utilization		95	%		93	%		89	%		2.2	%		4.5	%
Average sales price per gallon	$	1.62		$	1.67		$	1.68			(3.0	)%		(0.6	)%
Corn cost per bushel—CBOT equivalent	$	3.62		$	3.63		$	3.77			(0.3	)%		(3.7	)%
Average basis(1)	$	0.20		$	0.27		$	0.52			(26.0	)%		(48.1	)%
Delivered cost of corn	$	3.82		$	3.90		$	4.29			(2.1	)%		(9.1	)%
Total co-product tons sold (in thousands)		3,008.5			2,760.6			2,099.4			9.0	%		31.5	%
Co-product revenues as % of delivered cost of corn(2)		34.5	%		35.1	%		35.8	%		(1.7	)%		(2.0	)%
Average CBOT ethanol price per gallon	$	1.50		$	1.51		$	1.52			(0.1	)%		—	%
Average CBOT corn price per bushel	$	3.59		$	3.58		$	3.77			0.3	%		(5.0	)%

(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.

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Year Ended December 31, 2017 Compared to the Year Ended December 31, 2016

	Years Ended						Dollar Change			Percentage Change			Results as a Percentage of Net Sales for the Years Ended
	December 31,						Favorable			Favorable			December 31,
	2017			2016			(Unfavorable)			(Unfavorable)			2017			2016
	(dollars in thousands)
Net sales	$	1,632,255		$	1,624,758		$	7,497			0.5	%		100.0	%		100.0	%
Cost of goods sold		1,626,324			1,570,400			(55,924	)		(3.6	)%		99.6	%		96.7	%
Gross profit		5,931			54,358			(48,427	)		(89.1	)%		0.4	%		3.3	%
Selling, general and administrative expenses		31,516			30,849			(667	)		2.2	%		1.9	%		1.9	%
Income (loss) from operations		(25,585	)		23,509			(49,094	)		(208.8	)%		(1.6	)%		1.4	%
Fair value adjustments		473			(557	)		1,030			NM			0.0	%		(0.0	)%
Interest expense		(12,938	)		(22,406	)		9,468			42.3	%		(0.8	)%		(1.4	)%
Other expense, net		(345	)		(1	)		(344	)		NM			(0.0	)%		(0.0	)%
Income (loss) before provision for income taxes		(38,395	)		545			(38,940	)		NM			(2.4	)%		0.0	%
Provision (benefit) for income taxes		(321	)		(981	)		660			(67.3	)%		(0.0	)%		(0.1	)%
Consolidated net income (loss)		(38,074	)		1,526			(39,600	)		NM			(2.3	)%		0.1	%
Net (income) loss attributed to noncontrolling interests		3,110			(107	)		3,217			NM			0.2	%		—	%
Net income (loss) attributed to Pacific Ethanol, Inc.	$	(34,964	)	$	1,419		$	(36,383	)		NM			(2.1	)%		0.1	%
Preferred stock dividends		(1,265	)		(1,269	)		4			(0.3	)%		(0.1	)%		(0.1	)%
Income allocated to participating securities		—			(2	)		2			—			—	%		—	%
Income (loss) available to common stockholders	$	(36,229	)	$	148		$	(36,377	)		NM			(2.2	)%		0.0	%

Net Sales

The increase in our consolidated net sales for 2017 as compared to 2016 was primarily due to an increase in our total gallons sold, partially offset by a decrease in our average sales price per gallon.

We increased production gallons sold and our volume of co-products sold, for 2017 as compared to 2016, while decreasing third-party gallons sold. The increases in volumes of our production gallons and co-products sold are primarily due to additional volumes from our recently-acquired ICP production facility. We decreased third-party gallons sold due to an intentional reduction in less profitable third party sales.

Production Segment

Net sales of ethanol from our production segment increased by $45.7 million, or 6%, to $838.3 million for 2017 as compared to $792.6 million for 2016. Our total volume of production ethanol gallons sold increased by 43.1 million gallons, or 9%, to 527.2 million gallons for 2017 as compared to 484.1 million gallons for 2016. At our production segment’s average sales price per gallon of $1.59 for 2017, we generated $68.5 million in additional net sales from our production segment from the 43.1 million additional gallons of produced ethanol sold in 2017 as compared to 2016. The decline of $0.05, or 3%, in our production segment’s average sales price per gallon in 2017 as compared to 2016 reduced our net sales from our production segment by $22.8 million.

Net sales of co-products increased $11.2 million, or 4%, to $264.4 million for 2017 as compared to $253.2 million for 2016. Our total volume of co-products sold increased by 0.2 million tons to 3.0 million tons for 2017 from 2.8 million tons for 2016. At our average sales price per ton of $87.90 for 2017, we generated $21.8 million in additional net sales from the 0.2 million additional tons of co-products sold in 2017 as compared to 2016. The decline of $3.84, or 4%, in our average sales price per ton in 2017 as compared to 2016 decreased our net sales from our production segment by $10.6 million.

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Marketing Segment

Net sales of ethanol from our marketing segment decreased by $49.4 million, or 9%, to $529.5 million for 2017 as compared to $578.9 million for 2016.

Our total volume of ethanol gallons sold by our marketing segment increased by 27.5 million gallons, or 3%, to 952.0 million gallons for 2017 as compared to 924.5 million gallons for 2016. Our additional production gallons sold accounted for 43.1 million gallons of this increase, as noted above, and was offset by 15.6 million fewer third-party gallons sold.

The increase in production gallons sold by our marketing segment contributed insignificantly to net sales generated by our marketing segment, resulting in an additional $0.4 million in net sales, which were eliminated upon consolidation.

At our marketing segment’s average sales price per gallon of $1.67 for 2017, we generated $26.0 million in lower net sales from our marketing segment from the 15.6 million gallon reduction in third-party ethanol sold in 2017 as compared to 2016. Further, the decline of $0.05 per gallon, or 3%, in our marketing segment’s average sales price per gallon in 2017 as compared to 2016 reduced our net sales from third-party ethanol sold by our marketing segment by $23.4 million.

Cost of Goods Sold and Gross Profit

Our consolidated gross profit declined to $5.9 million for 2017 from $54.4 million for 2016, representing a gross margin of 0.4% for 2017 compared to 3.3% for 2016. Our consolidated gross profit decreased primarily due to significantly lower crush margins during the year resulting from lower ethanol prices. In addition, for the years ended December 31, 2017 and 2016, cost of goods sold included approximately $10.7 million and $7.4 million of larger than anticipated repair and maintenance related expenses to replace faulty equipment. 

Production Segment

Our production segment’s gross profit declined by $38.7 million to $3.1 million for 2017 as compared to $41.8 million for 2016. Of this decline, $38.9 million is attributable to lower margins, offset slightly by $0.2 million in higher gross profit attributable to the 43.1 million gallon increase in production volumes sold in 2017 as compared to 2016.

Marketing Segment

Our marketing segment’s gross profit declined by $9.8 million to $2.8 million for 2017 as compared to $12.6 million for 2016. Of this decline, $9.6 million is attributable to lower margins and $0.2 million is attributable to decreased third party marketing volumes in 2017 as compared to 2016.

Selling, General and Administrative Expenses

Our SG&A increased $0.7 million to $31.5 million for 2017 as compared to $30.8 million for the same period in 2016. The increase in SG&A is due to higher employee benefits, non-cash compensation and professional fees associated with our ICP acquisition, and higher overhead and other costs related to ICP’s business, partially offset by $3.6 million in gains associated with legal matters resolved in the first quarter of 2017.

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We expect SG&A of $34.0 million for 2018, or approximately $8.5 million per quarter.

Interest Expense

Interest expense declined by $9.5 million to $12.9 million for 2017 from $22.4 million for 2016. The decline primarily resulted from the refinance of debt balances acquired in connection with our acquisition of our Midwest plants, in which we replaced existing debt with lower cost debt.

Provision (Benefit) for Income Taxes

In 2017, we incurred book and tax losses, yet there were no prior years for which to carry back these losses. As a result, we will carry forward these tax losses, however, we must apply a valuation allowance against these net operating loss carryforwards until the realizability of these losses is more likely than not. Further, we revised the amount of our net deferred tax liabilities under the new Federal tax rates, and consequently recognized a gain on the reduction of these net tax liabilities of $0.3 million, resulting in a net tax benefit for 2017.

Net (Income) Loss Attributed to Noncontrolling Interests

Net (income) loss attributed to noncontrolling interests relates to our consolidated treatment of Pacific Aurora. Beginning in 2016, we consolidated the assets associated with Pacific Aurora before and after the admission of a 26% equity owner of Pacific Aurora. As a result, we reduced our consolidated net income (loss) for the noncontrolling interests, which were the ownership interests that we did not own.

Preferred Stock Dividends

Shares of our Series B Preferred Stock are entitled to quarterly cumulative dividends payable in arrears in an amount equal to 7% per annum of the purchase price per share of the Series B Preferred Stock. We accrued and paid in cash dividends of $1.3 million for each of 2017 and 2016 in respect of our Series B Preferred Stock.

Year Ended December 31, 2016 Compared to the Year Ended December 31, 2015

	Years Ended						Dollar Change			Percentage Change			Results as a Percentage of Net Sales for the Years Ended
	December 31,						Favorable			Favorable			December 31,
	2016			2015			(Unfavorable)			(Unfavorable)			2016			2015
	(dollars in thousands)
Net sales	$	1,624,758		$	1,191,176		$	433,582			36.4	%		100.0	%		100.0	%
Cost of goods sold		1,570,400			1,180,810			389,590			33.0	%		96.7	%		99.1	%
Gross profit		54,358			10,366			43,992			424.4	%		3.3	%		0.9	%
Selling, general and administrative expenses		30,849			26,368			(4,481	)		(17.0	)%		1.9	%		2.2	%
Asset impairment		—			1,970			1,970			100.0	%		—%			0.2	%
Income (loss) from operations		23,509			(17,972	)		41,481			NM			1.4	%		(1.5	)%
Fair value adjustments		(557	)		1,641			(2,198	)		NM			(0.0	)%		0.1	%
Interest expense		(22,406	)		(12,594	)		(9,812	)		(77.9	)%		(1.4	)%		(1.1	)%
Other income (expense), net		(1	)		18			(19	)		NM			(0.0	)%		—	%
Income (loss) before provision for income taxes		545			(28,907	)		29,452			NM			0.0	%		(2.4	)%
Provision (benefit) for income taxes		(981	)		(10,034	)		(9,053	)		(90.2	)%		(0.1	)%		(0.8	)%
Consolidated net income (loss)		1,526			(18,873	)		20,399			NM			0.1	%		(1.6	)%
Net (income) loss attributed to noncontrolling interests		(107	)		87			(194	)		NM			—	%		—	%
Net income (loss) attributed to Pacific Ethanol, Inc.	$	1,419		$	(18,786	)	$	20,205			NM			0.1	%		(1.6	)%
Preferred stock dividends		(1,269	)		(1,265	)		(4	)		(0.3	)%		(0.1	)%		(0.1	)%
Income allocated to participating securities		(2	)		—			(2	)		NM			—%			—%
Income (loss) available to common stockholders	$	148		$	(20,051	)	$	20,199			NM			0.0	%		(1.7	)%

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Net Sales

The increase in our consolidated net sales for 2016 as compared to 2015 was primarily due to an increase in our total gallons sold.

We increased both production and third-party gallons sold, and our volume of co-products sold, for 2016 as compared to 2015. The increases in volumes of our production gallons and co-products sold are primarily due to additional volumes from our plants located in the Midwest, as well as third-party sales. In addition, we expanded our customer base and our sales to a larger national footprint with the addition of regions we cover with our Midwest plants.

Our average sales price per gallon remained relatively flat at $1.67 for 2016 compared to our average sales price per gallon of $1.68 for 2015. Similarly, the average CBOT ethanol price per gallon, remained relatively flat at $1.51 for 2016 compared to $1.52 for 2015.

Production Segment

Net sales of ethanol from our production segment increased by $264.9 million, or 50%, to $792.6 million for 2016 as compared to $527.7 million for 2015. Our total volume of production ethanol gallons sold increased by 164.9 million gallons, or 52%, to 484.1 million gallons for 2016 as compared to 319.2 million gallons for 2015. At our production segment’s average sales price per gallon of $1.62 for 2016, we generated $267.0 million in additional net sales from our production segment from the 164.9 million additional gallons of produced ethanol sold in 2016 as compared to 2015. The decline of $0.01, or 0.6%, in our production segment’s average sales price per gallon in 2016 as compared to 2015 reduced our net sales from our production segment by $2.1 million.

Net sales of co-products increased $70.7 million, or 39%, to $253.2 million for 2016 as compared to $182.5 million for 2015. Our total volume of co-products sold increased by 0.7 million tons to 2.8 million tons for 2016 from 2.1 million tons for 2015. At our average sales price per ton of $91.74 for 2016, we generated $60.6 million in additional net sales from the 0.7 million additional tons of co-products sold in 2016 as compared to 2015. In addition, the increase of $4.82, or 5.5%, in our average sales price per ton in 2016 as compared to 2015 increased our net sales from our production segment by $10.1 million.

Marketing Segment

Net sales of ethanol from our marketing segment increased by $98.0 million, or 20%, to $579.0 million for 2016 as compared to $481.0 million for 2015.

Our total volume of ethanol gallons sold by our marketing segment increased by 223.0 million gallons, or 32%, to 924.5 million gallons for 2016 as compared to 701.5 million gallons for 2015. Our additional production gallons sold accounted for 164.9 million gallons of this increase, as noted above, and our additional third-party gallons sold accounted for 58.1 million gallons of this increase.

The increase in production gallons sold by our marketing segment contributed insignificantly to net sales generated by our marketing segment, resulting in an additional $2.6 million in net sales, which were eliminated upon consolidation.

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At our marketing segment’s average sales price per gallon of $1.72 for 2016, we generated $99.6 million in additional net sales from our marketing segment from the 58.1 million gallons in additional third-party ethanol sold in 2016 as compared to 2015. However, the decline of less than $0.01, or 0.3%, in our marketing segment’s average sales price per gallon in 2016 as compared to 2015 reduced our net sales from third-party ethanol sold by our marketing segment by $1.6 million.

Cost of Goods Sold and Gross Profit

Our consolidated gross profit improved significantly to $54.4 million for 2016 from $10.4 million for 2015, representing a gross margin of 3.3% for 2016 compared to 0.9% for 2015. Our consolidated gross profit increased primarily due to a decline of $0.39 in our average delivered cost of corn per bushel in 2016 as compared to 2015.

Production Segment

Our production segment improved our consolidated gross profit by $40.6 million for 2016 as compared to 2015. Of this amount, $26.4 million is attributable to higher margins resulting primarily from our lower corn costs in 2016 as compared to 2015, and $14.2 million in higher gross profit is attributed to the 164.9 million gallon increase in production volumes sold in 2016 as compared to 2015.

Marketing Segment

Our marketing segment improved our consolidated gross profit by $3.4 million for 2016 as compared to 2015. Of this amount, $2.2 million is attributable to the 58.1 million gallon increase in third party marketing volumes in 2016 as compared to 2015, and $1.2 million is attributable to higher margins from our marketing segment in 2016 as compared to 2015.

Selling, General and Administrative Expenses

Our SG&A increased $4.5 million to $30.8 million for 2016 as compared to $26.3 million for the same period in 2015. The increase in SG&A is due to increased professional fees relating to our litigation matters, our costs associated with our transaction with ACEC and refinancing efforts during 2016 and an increase in compensation costs.

Interest Expense

Interest expense increased by $9.8 million to $22.4 million for 2016 from $12.6 million for 2015. Increased interest expense is primarily related to a full year of debt inherited in the acquisition of our Midwest facilities as well as increased debt discount amortization resulting from our early payoff of the debt. In December 2016, we refinanced our outstanding plant debt with new term and revolving debt at interest rates much lower than the prior debt which should result in lower interest expense in future periods.

Provision (Benefit) for Income Taxes

In 2016, we generated taxable income, however, we were able to offset taxable income against net operating losses in prior years. Further, we revised our estimate of our valuation allowance related to prior alternative minimum tax credits, which relates to a change in the tax code during the year, resulting in a net tax benefit for 2016.

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Net (Income) Loss Attributed to Noncontrolling Interests

Net (income) loss attributed to noncontrolling interests relates to our consolidated treatment of Pacific Aurora as previously discussed, and PE Op Co., which indirectly owns our plants located on the West Coast. In 2015, PE Op Co. was not wholly owned for the entire year, but was wholly owned at the end of 2015.

Preferred Stock Dividends

Shares of our Series B Preferred Stock are entitled to quarterly cumulative dividends payable in arrears in an amount equal to 7% per annum of the purchase price per share of the Series B Preferred Stock. We accrued and paid in cash dividends of $1.3 million for each of 2016 and 2015 in respect of our Series B Preferred Stock.

Liquidity and Capital Resources

During 2017, we funded our operations primarily from cash on hand, cash generated from our operations, proceeds from new credit facilities, advances from our revolving credit facilities, proceeds from the issuance of additional senior notes, income tax refunds and proceeds from warrant exercises. A portion of these funds were also used to acquire ICP, make payments on our term debt, make capital expenditures, make payments on our capital leases and pay dividends in respect of our Series B Preferred Stock.

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 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 Year-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).

	December 31, 2017		December 31, 2016
Cash and cash equivalents	$	49,489	$	64,259
Current assets	$	203,246	$	235,201
Property and equipment, net	$	508,352	$	465,190
Current liabilities	$	90,706	$	78,841
Long-term debt, noncurrent portion	$	221,091	$	188,028
Working capital	$	112,540	$	156,360
Working capital ratio		2.24		2.98

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Restricted Net Assets

At December 31, 2017, we had approximately $302.9 million of net assets at our subsidiaries that were not available to be transferred to Pacific Ethanol, Inc. in the form of dividends, distributions, loans or advances due to restrictions contained in the credit facilities of these subsidiaries.

Changes in Working Capital and Cash Flows

Working capital decreased to $112.5 million at December 31, 2017 from $156.4 million at December 31, 2016 as a result of a decrease of $32.0 million in current assets and an increase of $11.9 million in current liabilities.

Current assets decreased primarily due to a decrease of $14.8 million in cash, $6.7 million in prepaid inventory, $5.9 million in accounts receivable, $5.0 million in income tax receivables and $1.1 million in derivative and other assets, partially offset by an increase of $1.5 million in inventories.

Our cash and cash equivalents decreased by $14.8 million at December 31, 2017 as compared to December 31, 2016 primarily due to $50.4 million used in our investing activities in connection with our plant improvement initiatives and our acquisition of ICP, and an additional $0.8 million used in our net financing activities, partially offset by $36.5 million of cash generated from our operations.

Our current liabilities increased by $11.9 million at December 31, 2017 as compared to December 31, 2016 primarily due to an increase of $9.5 million in current portion of long-term debt, $4.1 million in accounts payable and accrued liabilities, partially offset by a decrease of $1.5 million in derivative and other current liabilities.

Cash provided by or used in our Operating Activities

Cash provided by our operating activities declined by $0.7 million in 2017 as compared to 2016. We generated $36.5 million of cash from our operating activities in 2017. Specific factors that contributed to the decrease in cash provided by our operating activities include:

● a decrease related to net income (loss) of $36.5 million;

● a decrease related to accounts payable and accrued expenses of $14.8 million due to the timing of payments and higher sales volumes;

● a decrease related to interest expense added to plant term debt of $9.5 million as we did not add any interest to plant debt balances in 2017; and

● a decrease related to prepaid expenses and other assets of $0.5 million due to the collection of income tax refunds.

These amounts were partially offset by:

● an increase related to accounts receivable of $42.8 million primarily due to the timing of collections; and

● an increase related to inventories and prepaid inventory of $15.0 million due to the timing of purchases.

Cash used in our Investing Activities

Cash used in our investing activities increased by $35.8 million in 2017 as compared to 2016. We used $50.4 million of cash in our investing activities in 2017. The increase in cash used in our investing activities is primarily due to $29.6 million of net cash used in our acquisition of ICP and an increase of $1.7 million in capital expenditures.

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Cash provided by or used in our Financing Activities

Cash used in our financing activities declined by $9.1 million in 2017 as compared to 2016. We used $0.8 million of cash in our financing activities in 2017. The decrease in cash used in our financing activities is primarily due to the following activities:

● a decrease of $91.3 million in proceeds from credit agreements and assessment financing, in the current year as compared to our debt refinancing transactions in the prior year; and

● a decrease of $30.0 million from the sale of a portion of our equity interest in Pacific Aurora in the prior year.

These amounts were partially offset by:

● a decrease of $112.1 million in payments in respect of term and revolving debt; and

● a decrease of $6.5 million in payments on capital leases.

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 matures on August 2, 2022. 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.

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) divided by the sum of interest expense, capital expenditures, 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):

	Years Ended December 31,
	2017		2016
Fixed Charge Coverage Ratio Requirement		2.00		2.00
Actual		2.79		7.88
Excess		0.79		5.88

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Pacific Ethanol has guaranteed all of Kinergy’s obligations under the credit facility. As of December 31, 2017, Kinergy had an outstanding balance of $49.5 million and an unused availability under the credit facility of $27.4 million.

Pekin Credit Facilities

On December 15, 2016, our wholly-owned subsidiary, Pacific Ethanol Pekin, Inc., or Pekin, entered into term and revolving credit facilities. Pekin borrowed $64.0 million under a term loan facility that matures on August 20, 2021 and $32.0 million under a revolving credit facility that matures on February 1, 2022. The Pekin credit facilities are secured by a first-priority security interest in all of Pekin’s assets. Interest accrues under the Pekin credit facilities at an annual rate equal to the 30-day LIBOR plus 3.75%, payable monthly. Pekin is required to make quarterly principal payments in the amount of $3.5 million on the term loan beginning on May 20, 2017 and a principal payment of $4.5 million at maturity on August 20, 2021. 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, Pekin is required to maintain not less than $20.0 million in working capital and an annual debt coverage ratio of not less than 1.25 to 1.0.

On August 7, 2017, 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%. Pekin and its lender also agreed that 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 ended December 31, 2017. Pekin’s actual Debt Service Coverage Ratio was 0.17 to 1.00 for the fiscal year ended December 31, 2017, 0.02 in excess of the required 0.15 to 1.00. For the month ended January 31, 2018, Pekin was not in compliance with its working capital requirement due to larger than anticipated repair and maintenance related expenses to replace faulty equipment. Pekin has received a waiver from its lender for this noncompliance. Further, the lender decreased Pekin’s working capital covenant requirement to $13.0 million for the month ended February 28, 2018, excluding the $3.5 million principal payment due in May 2018 in the calculation. As of the filing of this report, we believe Pekin is in compliance with its working capital requirement.

ICP Credit Facilities

On September 15, 2017, ICP entered into term and revolving credit facilities. ICP borrowed $24.0 million under term loan facility that matures on September 20, 2021 and $18.0 million under a 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 consecutive principal payments in the amount of $1.5 million. 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. Prepayment of these facilities is subject to a prepayment penalty. Under the terms of the credit facilities, ICP is required to maintain not less than $8.0 million in working capital and an annual debt coverage ratio of not less than 1.5 to 1.0, beginning for the year ended December 31, 2018.

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Pacific Aurora Credit Facility

On December 15, 2016, Pacific Aurora entered into 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 June 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 was required to maintain not less than $22.5 million in working capital through June 30, 2017, not less than $24.0 million in working capital after June 30, 2017 and an annual debt service coverage ratio of not less than 1.50 to 1.00. These covenants were partially amended, as noted below.

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.

At December 31, 2017, Pacific Aurora was not in compliance with its working capital and Debt Service Coverage Ratio requirements. We did not utilize the credit facility in 2017 and have no plans to draw on the facility at this time, having addressed the liquidity and capital needs of Pacific Aurora through other means. Consequently, we are in discussions with our lender to either amend the credit facility or terminate it.

Pacific Ethanol, Inc. Notes Payable

On December 12, 2016, we entered into a Note Purchase Agreement with five accredited investors. On December 15, 2016, under the terms of the Note Purchase Agreement, we sold $55.0 million in aggregate principal amount of our senior secured notes to the investors in a private offering for aggregate gross proceeds of 97% of the principal amount of the notes sold. On June 26, 2017, we entered into a second Note Purchase Agreement with five accredited investors. On June 30, 2017, under the terms of the second Note Purchase Agreement, we sold an additional $13.9 million in aggregate principal amount of our senior secured notes to the investors in a private offering for aggregate gross proceeds of 97% of the principal amount of the notes sold, for a total of $68.9 million in aggregate principal amount of senior secured notes.

The notes 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% from the closing through December 14, 2017, (ii) the greater of 1% and the three-month LIBOR, plus 9% between December 15, 2017 and December 14, 2018, and (iii) the greater of 1% and the three-month LIBOR plus 11% between December 15, 2018 and the maturity date. The interest rate increases by an additional 2% per annum above the interest rate otherwise applicable upon the occurrence and during the continuance of an event of default until cured. Interest is payable in cash in arrears on the 15th calendar day of each March, June, September and December. 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.

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Effects of Inflation

The impact of inflation was not significant to our financial condition or results of operations for 2017, 2016 or 2015.

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Contractual Obligations

The following table outlines payments due under our significant contractual obligations (in thousands):

Contractual Obligations At December 31, 2017	2018		2019		2020		2021		2022		Thereafter		Total
Sourcing commitments(1)	$	30,066	$	—	$	—	$	—	$	—	$	—	$	30,066
Debt principal		20,000		88,948		20,000		16,000		99,477		—		244,425
Debt interest(2)		15,254		14,692		5,971		4,844		1,824		2		42,587
Capital projects		7,296		—		—		—		—		—		7,296
Operating leases(3)		11,841		9,236		7,042		4,074		3,894		5,530		41,617
Capital leases(3)		613		45		45		34		—		—		737
Preferred dividends(4)		1,265		1,265		1,265		1,265		1,265		1,265		7,590
Total commitments	$	86,335	$	114,186	$	34,323	$	26,217	$	106,460	$	6,797	$	374,318

(1) Unconditional fixed purchase commitments for production materials incurred in the normal course of business.

(2) Payments based on interest rates and balances as of December 31, 2017 through maturity.

(3) Future minimum payments under capital and non-cancelable operating leases.

(4) Represents dividends on 926,942 shares of Series B Preferred Stock. Dividends accrue until Series B Preferred Stock is converted to common stock or redeemed. The “thereafter” amount includes only one additional year of dividends.

The above table outlines our obligations as of December 31, 2017 and does not reflect the changes in our obligations that occurred after that date.

Critical Accounting Policies

Our discussion and analysis of our financial condition and results of operations is based upon our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America. The preparation of these financial statements requires us to make estimates and judgments 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 amount of net sales and expenses for each period. The following represents a summary of our critical accounting policies, defined as those policies that we believe are the most important to the portrayal of our financial condition and results of operations and that require management’s most difficult, subjective or complex judgments, often as a result of the need to make estimates about the effects of matters that are inherently uncertain.

Revenue Recognition

We recognize revenue when it is realized or realizable and earned. We consider revenue realized or realizable and earned when there is persuasive evidence of an arrangement, delivery has occurred, the sales price is fixed or determinable, and collection is reasonably assured. We derive revenue primarily from sales of ethanol and related co-products. We recognize revenue when title transfers to our customers, which is generally upon the delivery of these products to a customer’s designated location. These deliveries are made in accordance with sales commitments and related sales orders entered into with customers either verbally or in written form. The sales commitments and related sales orders provide quantities, pricing and conditions of sales. In this regard, we engage in three basic types of revenue generating transactions:

● As a producer. Sales as a producer consist of sales of our inventory produced at our ethanol production facilities.

● As a merchant. Sales as a merchant consist of sales to customers through purchases from third-party suppliers in which we may or may not obtain physical control of the ethanol in which shipments are directed from our suppliers to our terminals or direct to our customers but for which we accept the risk of loss in the transactions.

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● As an agent. Sales as an agent consist of sales to customers through purchases from third-party suppliers in which the risks and rewards of inventory ownership remain with third-party suppliers and we receive a predetermined service fee under these transactions.

The following table shows our net sales generated as a producer, a merchant and as an agent for the years presented (in thousands):

	For the Years Ended December 31,
	2017		2016		2015
Producer	$	1,102,722	$	1,045,807	$	710,114
Merchant		527,869		577,347		479,551
Agent		1,664		1,604		1,511
	$	1,632,255	$	1,624,758	$	1,191,176

Revenue from sales of third-party ethanol is recorded net of costs when we are acting as an agent between a customer and a supplier and gross when we are a principal to the transaction. Several factors are considered to determine whether we are acting as an agent or principal, most notably whether we are the primary obligor to the customer, whether we have inventory risk and related risk of loss or whether we add meaningful value to the supplier’s product or service. Consideration is also given to whether we have latitude in establishing the sales price or have credit risk, or both. When we act as an agent, we record revenues on a net basis, or our predetermined fees and any associated freight, based upon the amount of net revenues retained in excess of amounts paid to suppliers.

We record revenues based upon the gross amounts billed to our customers in transactions where we act as a producer or a merchant and obtain title to ethanol and therefore own the product and any related unmitigated inventory risk for the ethanol, regardless of whether we actually obtain physical control of the product.

Impairment of Long-Lived Assets

Our long-lived assets have been primarily associated with our ethanol production facilities, reflecting their original cost, adjusted for depreciation and any subsequent impairment.

We assess the impairment of long-lived assets, including property and equipment, when events or changes in circumstances indicate that the fair value of an asset could be less than the net book value of the asset. Generally, we assess long-lived assets for impairment by first determining the forecasted, undiscounted cash flows each asset is expected to generate plus the net proceeds expected from the sale of the asset. If the amount of proceeds is less than the carrying value of the asset, we then determine the fair value of the asset. An impairment loss would be recognized when the fair value is less than the related net book value, and an impairment expense would be recorded in the amount of the difference. Forecasts of future cash flows are judgments based on our experience and knowledge of our operations and the industry in which we operate. These forecasts could be significantly affected by future changes in market conditions, the economic environment, including inflation, and the purchasing decisions of our customers.

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We review our intangible assets with indefinite lives at least annually or more frequently if impairment indicators arise. In our review, we determine the fair value of these assets using market multiples and discounted cash flow modeling and compare it to the net book value of the acquired assets.

In 2015, we recorded an impairment charge of $2.0 million on our long-lived assets related to the abandonment of certain accounting and information technology systems following our integration of our Midwest plants. We did not recognize any asset impairment charges in 2017 and 2016.

Valuation Allowance for Deferred Taxes

We account for income taxes under the asset and liability approach, where deferred tax assets and liabilities are determined based on differences between financial reporting and tax bases of assets and liabilities, and are measured using enacted tax rates and laws that are expected to be in effect when the differences reverse. Valuation allowances are established when necessary to reduce deferred tax assets to the amounts expected to be realized.

We evaluate our deferred tax asset balance for realizability. To the extent we believe it is more likely than not that some portion or all of our deferred tax assets will not be realized, we will establish a valuation allowance against the deferred tax assets. Realization of our deferred tax assets is dependent upon future taxable income during the periods in which the associated temporary differences become deductible. We consider the scheduled reversal of deferred tax liabilities, projected future taxable income and tax planning strategies in making this assessment. These changes, if any, may require possible material adjustments to these deferred tax assets, resulting in a reduction in net income or an increase in net loss in the period when such determinations are made.

Our pre-tax consolidated loss was $38.4 million, compared to income of $0.5 million and a loss of $28.9 million for the years ended December 31, 2017, 2016 and 2015, respectively. In 2016, we carried back a portion of our losses to apply to taxable income in 2014, however, based on our current and prior results, we do not have significant evidence to support a conclusion that we will more likely than not be able to benefit from our remaining deferred tax assets. As such, we have recorded a valuation allowance against our net deferred tax assets.

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Derivative Instruments

We evaluate our contracts to determine whether the contracts are derivative instruments. Management may elect to exempt certain forward contracts that meet the definition of a derivative from derivative accounting as normal purchases or normal sales. Normal purchases and normal sales are contracts that provide for the purchase or sale of something other than a financial instrument or derivative instrument that will be delivered in quantities expected to be used or sold over a reasonable period in the normal course of business. Contracts that meet the requirements of normal purchases or sales are documented as normal and exempted from the fair value accounting and reporting requirements of derivative accounting.

We enter into short-term cash, option and futures contracts as a means of securing purchases of corn, natural gas and sales of ethanol and managing exposure to changes in commodity prices. All of our exchange-traded derivatives are designated as non-hedge derivatives for accounting purposes, with changes in fair value recognized in net income. Although the contracts are economic hedges of specified risks, they are not designated as and accounted for as hedging instruments.

Realized and unrealized gains and losses related to exchange-traded derivative contracts are included as a component of cost of goods sold in the accompanying financial statements. The fair values of contracts entered through commodity exchanges are presented on the accompanying balance sheet as derivative instruments. The selection of normal purchase or sales contracts, and use of hedge accounting, are accounting policies that can change the timing of recognition of gains and losses in the statement of operations.

Accounting for Business Combinations

Determining the fair value of assets acquired and liabilities assumed in a business combination is considered a critical accounting estimate because the allocation of the purchase price to assets acquired and liabilities assumed based upon fair values requires significant management judgment and the use of subjective measurements. Variability in industry conditions and changes in assumptions or subjective measurements used to allocate fair value are reasonably possible and may have a material impact on our financial position, liquidity or results of operations.

Allowance for Doubtful Accounts

We sell ethanol primarily to gasoline refining and distribution companies, sell corn oil to poultry and biodiesel customers and sell other co-products to dairy operators and animal feed distributors. We had significant concentrations of credit risk from sales of our ethanol as of December 31, 2017 and 2016, as described in Note 1 to our consolidated financial statements included elsewhere in this report. However, historically, those ethanol customers have had good credit ratings and we have collected the amounts billed to those customers. Receivables from customers are generally unsecured. We continuously monitor our customer account balances and actively pursue collections on past due balances.

We maintain an allowance for doubtful accounts for balances that appear to have specific collection issues. Our 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, we have been unsuccessful in our collection efforts, we consider recording a bad debt allowance for the balance in question. We would eventually write-off accounts included in our allowance when we have determined that collection is not likely. The factors considered in reaching this determination are the apparent financial condition of the customer, and our success in contacting and negotiating with the customer.

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We recognized a bad debt expense of $5,000 and $306,000 and bad debt recoveries of $354,000 for the years ended December 31, 2017, 2016 and 2015, respectively.

Impact of New Accounting Pronouncements

See “Note 1 – Organization and Significant Accounting Policies – Recent Accounting Pronouncements” of the Notes to Consolidated Financial Statements commencing on page F-19 of this report.

Item 7A. 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, specialty alcohols and 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 the CBOT or the Oil Price Information Service. Under these fixed-priced arrangements, we are exposed to risk of a decrease 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. Additionally, we also enter into volume contracts with our vendors to fix the purchase price. 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.

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.

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These derivatives are not designated for special hedge accounting treatment, and as such, the changes in the fair values of these contracts are recorded on the balance sheet and recognized immediately in cost of goods sold. We recognized losses of $4.2 million, income of $1.4 million and losses of $0.3 million related to settled non-designated hedges as the change in the fair values of these contracts for the years ended December 31, 2017, 2016 and 2015, respectively.

At December 31, 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 December 31, 2017, which may differ materially from actual results, are as follows (in millions):

Commodity	Year Ending December 31,  2017 Volume		Unit of Measure		Approximate Adverse Change to Pre-Tax Income
Ethanol		952.0		Gallons	$	85.8
Corn		188.3		Bushels	$	68.2

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 December 31, 2017, $244.4 million of our long-term debt was variable-rate in nature. Based on a 100 basis point (1.00%) increase in the interest rate on our long-term debt, on an annualized basis, our pre-tax income for the year ended December 31, 2017 would have been negatively impacted by approximately $2.4 million.

Item 8. Financial Statements and Supplementary Data.

Reference is made to the financial statements, which begin at page F-1 of this report.

Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.

None.

Item 9A. 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 and 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 December 31, 2017 that our disclosure controls and procedures were effective at a reasonable assurance level.

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Management’s Report on Internal Control over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act. Our internal control over financial reporting is designed 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. Our internal control over financial reporting includes those policies and procedures that:

(i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of our assets;

(ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that our receipts and expenditures are being made only in accordance with authorizations of our management and directors; and

(iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of our assets that could have a material effect on our financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

A material weakness is defined by the Public Company Accounting Oversight Board’s Audit Standards AS 2201 as being a deficiency, or combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of the company’s annual or interim financial statements will not be prevented or detected on a timely basis by the company’s internal controls.

Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework set forth in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our evaluation under the framework set forth in Internal Control — Integrated Framework (2013), our management concluded that our internal control over financial reporting was effective as of December 31, 2016.

RSM US LLP, an independent registered public accounting firm, has issued an attestation report on our internal control over financial reporting as of December 31, 2017. That report is included in Part IV of this report.

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.

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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.

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.

Item 9B. Other Information.

None.

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PART III

Item 10. Directors, Executive Officers and Corporate Governance.

The information under the captions “Information about our Board of Directors, Board Committees and Related Matters” and “Section 16(a) Beneficial Ownership Reporting Compliance,” appearing in the Proxy Statement, is hereby incorporated by reference.

Item 11. Executive Compensation.

The information under the caption “Executive Compensation and Related Information,” appearing in the Proxy Statement, is hereby incorporated by reference.

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.

The information under the captions “Security Ownership of Certain Beneficial Owners and Management” and “Equity Compensation Plan Information,” appearing in the Proxy Statement, is hereby incorporated by reference.

Item 13. Certain Relationships and Related Transactions, and Director Independence.

The information under the captions “Certain Relationships and Related Transactions” and “Information about our Board of Directors, Board Committees and Related Matters—Director Independence” appearing in the Proxy Statement, is hereby incorporated by reference.

Item 14. Principal Accounting Fees and Services.

The information under the caption “Audit Matters—Principal Accountant Fees and Services,” appearing in the Proxy Statement, is hereby incorporated by reference.

PART IV

Item 15. Exhibits, Financial Statement Schedules.

(a)(1) Financial Statements

Reference is made to the financial statements listed on and attached following the Index to Consolidated Financial Statements contained on page F-1 of this report.

(a)(2) Financial Statement Schedules

None.

(a)(3) Exhibits

Reference is made to the exhibits listed on the Index to Exhibits.

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Index to Consolidated Financial Statements

Reports of Independent Registered Public Accounting Firm	F-2
Consolidated Balance Sheets as of December 31, 2017 and 2016	F-5
Consolidated Statements of Operations for the Years Ended December 31, 2017, 2016 and 2015	F-7
Consolidated Statements of Comprehensive Income (Loss) for the Years Ended December 31, 2017, 2016 and 2015	F-8
Consolidated Statements of Stockholders’ Equity for the Years Ended December 31, 2017, 2016 and  2015	F-9
Consolidated Statements of Cash Flows for the Years Ended December 31, 2017, 2016 and 2015	F-10
Notes to Consolidated Financial Statements	F-12

 F-1

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Stockholders and the Board of Directors of
Pacific Ethanol, Inc.

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of Pacific Ethanol, Inc. and its subsidiaries (the “Company”) as of December 31, 2017 and 2016, the related consolidated statements of operations, other comprehensive income (loss), stockholders’ equity and cash flows for each of the three years in the period ended December 31, 2017, and the related notes to the consolidated financial statements (collectively, the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2017 and 2016, and the results of its operations and its cash flows for each of the years in the three year period ended December 31, 2017, in conformity with accounting principles generally accepted in the United States of America.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (“PCAOB”), the Company’s internal control over financial reporting as of December 31, 2017, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission in 2013, and our report dated March 15, 2018, expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.

Basis for Opinion

These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

/s/ RSM US LLP

We have served as the Company’s auditor since 2015.

Sioux Falls, South Dakota
March 15, 2018

 F-2

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Stockholders and the Board of Directors of
Pacific Ethanol, Inc.

Opinion on the Internal Control Over Financial Reporting

We have audited Pacific Ethanol, Inc.’s (the “Company”) internal control over financial reporting as of December 31, 2017, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission in 2013. In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2017, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission in 2013.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (“PCAOB”), the consolidated balance sheets as of December 31, 2017 and 2016, the related consolidated statements of operations, other comprehensive income (loss), stockholders’ equity and cash flows for each of the three years in the period ended December 31, 2017 of the Company and our report dated March 15, 2018 expressed an unqualified opinion.

Basis for Opinion

The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting in the accompanying Management’s Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

Definition and Limitations of Internal Control Over Financial Reporting

A company’s internal control over financial reporting is a process designed 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. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

 F-3

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

/s/ RSM US LLP

Sioux Falls, South Dakota 

March 15, 2018

 F-4

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

	December 31,
	2017		2016
ASSETS
Current Assets:
Cash and cash equivalents	$	49,489	$	64,259
Accounts receivable, net of allowance for doubtful accounts of $19 and $331, respectively		80,344		86,275
Inventories		61,550		60,070
Prepaid inventory		3,281		9,946
Income tax receivables		743		5,730
Derivative assets		998		978
Other current assets		6,841		7,943
Total current assets		203,246		235,201
Property and equipment, net		508,352		465,190
Other Assets:
Intangible assets		2,678		2,678
Other assets		6,020		5,169
Total other assets		8,698		7,847
Total Assets	$	720,296	$	708,238

The accompanying notes are an integral part of these consolidated financial statements.

F-5

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

	December 31,
	2017			2016
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities:
Accounts payable – trade	$	39,738		$	37,051
Accrued liabilities		21,673			20,280
Current portion – capital leases		592			794
Current portion – long-term debt		20,000			10,500
Derivative liabilities		2,307			4,115
Other current liabilities		6,396			6,101
Total current liabilities		90,706			78,841
Long-term debt, net of current portion		221,091			188,028
Capital leases, net of current portion		123			547
Warrant liabilities at fair value		—			651
Other liabilities		24,676			21,910
Total Liabilities		336,596			289,977
Commitments and contingencies (Notes 1, 8, 9 and 14)
Stockholders’ Equity:
Preferred stock, $0.001 par value; 10,000,000 shares authorized:
Series A: 1,684,375 shares authorized; no shares issued and outstanding as of December 31, 2017 and 2016		—			—
Series B: 1,580,790 shares authorized; 926,942 shares issued and outstanding as of December 31, 2017 and 2016; liquidation preference of $18,075 as of December 31, 2017		1			1
Common stock, $0.001 par value; 300,000,000 shares authorized; 43,984,975 and 39,772,238 shares issued and outstanding as of December 31, 2017 and 2016, respectively		44			40
Non-voting common stock, $0.001 par value; 3,553,000 shares authorized; 896 and 3,540,132 shares issued and outstanding as of December 31, 2017 and 2016, respectively		—			4
Additional paid-in capital		927,090			922,698
Accumulated other comprehensive loss		(2,234	)		(2,620	)
Accumulated deficit		(568,462	)		(532,233	)
Total Pacific Ethanol, Inc. stockholders’ equity		356,439			387,890
Noncontrolling interests		27,261			30,371
Total stockholders’ equity		383,700			418,261
Total Liabilities and Stockholders’ Equity	$	720,296		$	708,238

The accompanying notes are an integral part of these consolidated financial statements.

F-6

PACIFIC ETHANOL, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS
(in thousands, except per share data)

	Years Ended December 31,
	2017				2016		2015
Net sales	$	1,632,255		$	1,624,758		$	1,191,176
Cost of goods sold		1,626,324			1,570,400			1,180,810
Gross profit		5,931			54,358			10,366
Selling, general and administrative expenses		31,516			30,849			26,368
Asset impairment		—			—			1,970
Income (loss) from operations		(25,585	)		23,509			(17,972	)
Fair value adjustments and warrant inducements		473			(557	)		1,641
Interest expense		(12,938	)		(22,406	)		(12,594	)
Other income (expense), net		(345	)		(1	)		18
Income (loss) before provision for income taxes		(38,395	)		545			(28,907	)
Provision (benefit) for income taxes		(321	)		(981	)		(10,034	)
Consolidated net income (loss)		(38,074	)		1,526			(18,873	)
Net (income) loss attributed to noncontrolling interests		3,110			(107	)		87
Net income (loss) attributed to Pacific Ethanol, Inc.	$	(34,964	)	$	1,419		$	(18,786	)
Preferred stock dividends	$	(1,265	)	$	(1,269	)	$	(1,265	)
Income allocated to participating securities		—			(2	)		—
Income (loss) available to common stockholders	$	(36,229	)	$	148		$	(20,051	)
Income (loss) per share, basic and diluted	$	(0.85	)	$	0.00		$	(0.60	)
Weighted-average shares outstanding, basic		42,745			42,182			33,173
Weighted-average shares outstanding, diluted		42,745			42,251			33,173

The accompanying notes are an integral part of these consolidated financial statements.

F-7

PACIFIC ETHANOL, INC.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(in thousands)

	Years Ended December 31,
	2017			2016			2015
Consolidated net income (loss)	$	(38,074	)	$	1,526		$	(18,873	)
Other comprehensive income (expense) – net gain (loss) arising during the period on defined benefit pension plans		386			(3,660	)		1,040
Total comprehensive loss		(37,688	)		(2,134	)		(17,833	)
Comprehensive (income) loss attributed to noncontrolling interests		3,110			(107	)		87
Comprehensive loss attributed to Pacific Ethanol, Inc.	$	(34,578	)	$	(2,241	)	$	(17,746	)

The accompanying notes are an integral part of these consolidated financial statements.

F-8

PACIFIC ETHANOL, INC.

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

(in thousands)

	Preferred Stock				Common Stock
	Shares		Amount		Shares		Amount		Additional Paid-In Capital		Accumulated Deficit			Accum. Other Comprehensive Income (Loss)			Non-Controlling Interests			Total
Balances, January 1, 2015		927	$	1		24,499	$	25	$	725,813	$	(512,332	)	$	—		$	4,475		$	217,982
Stock-based compensation expense – restricted stock issued to employees and directors, net of cancellations and tax		—		—		216		—		1,475		—			—			—			1,475
Pension plan adjustment		—		—		—		—		—		—			1,040			—			1,040
Warrant exercises		—		—		42		—		440		—			—			—			440
Shares issued in PE Central acquisition		—		—		17,758		18		174,555		—			—			—			174,573
Purchases of interests in PE Op Co.		—		—		—		—		560		—			—			(4,388	)		(3,828	)
Preferred stock dividends		—		—		—		—		—		(1,265	)		—			—			(1,265	)
Net loss		—		—		—		—		—		(18,786	)		—			(87	)		(18,873	)
Balances, December 31, 2015		927	$	1		42,515	$	43	$	902,843	$	(532,383	)	$	1,040		$	—		$	371,544
Stock-based compensation expense – restricted stock and options to employees and directors, net of cancellations and tax		—		—		659		1		2,281		—			—			—			2,282
Warrant exercises		—		—		138		—		1,338		—			—			—			1,338
ACEC contribution to form Pacific Aurora		—		—		—		—		5,761		—			—			10,739			16,500
Pension plan adjustment		—		—		—		—		—		—			(3,660	)		—			(3,660	)
Sale of Pacific Aurora interests to ACEC		—		—		—		—		10,475		—			—			19,525			30,000
Preferred stock dividends		—		—		—		—		—		(1,269	)		—			—			(1,269	)
Net income		—		—		—		—		—		1,419			—			107			1,526
Balances, December 31, 2016		927	$	1		43,312	$	44	$	922,698	$	(532,233	)	$	(2,620	)	$	30,371		$	418,261
Stock-based compensation expense – restricted stock and options to employees and directors, net of cancellations and tax		—		—		473		—		3,014		—			—			—			3,014
Warrant and option exercises		—		—		201		—		1,378		—			—			—			1,378
Pension plan adjustment		—		—		—		—		—		—			386			—			386
Preferred stock dividends		—		—		—		—		—		(1,265	)		—			—			(1,265	)
Net loss		—		—		—		—		—		(34,964	)		—			(3,110	)		(38,074	)
Balances, December 31, 2017		927	$	1		43,986	$	44	$	927,090	$	(568,462	)	$	(2,234	)	$	27,261		$	383,700

The accompanying notes are an integral part of these consolidated financial statements.

F-9

PACIFIC ETHANOL, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS 

(in thousands)

	For the Years Ended December 31,
	2017			2016			2015
Operating Activities:
Consolidated net income (loss)	$	(38,074	)	$	1,526		$	(18,873	)
Adjustments to reconcile consolidated net income (loss) to cash provided by (used in) operating activities:
Depreciation and amortization of intangibles		38,651			35,441			23,632
Fair value adjustments		(473	)		557			(1,641	)
Asset impairment		—			—			1,970
Deferred income taxes		169			(1,122	)		(2,023	)
Inventory valuation		2,678			—			509
Change in fair value on commodity derivative instruments		2,077			1,984			542
Amortization of deferred financing costs		503			137			272
Amortization of debt discounts		636			2,322			716
Noncash compensation		3,828			2,616			2,019
Bad debt expense (recovery)		5			306			(354	)
Interest expense added to plant term debt		—			9,451			—
Changes in operating assets and liabilities, net of effects from acquisitions:
Accounts receivable		17,562			(25,235	)		(15,950	)
Inventories		5,070			750			(13,296	)
Prepaid expenses and other assets		2,677			3,189			(1,093	)
Prepaid inventory		6,738			(3,973	)		5,622
Accounts payable and accrued expenses		(5,538	)		9,279			(10,045	)
Net cash provided by (used in) operating activities	$	36,509		$	37,228		$	(27,993	)
Investing Activities:
Additions to property and equipment	$	(20,866	)	$	(19,171	)	$	(20,507	)
Purchase of ICP, net of cash acquired		(29,574	)		—			—
Proceeds (payments) for cash collateralized letters of credit		—			4,574			(4,574	)
Net cash from acquisition of PE Central		—			—			18,756
Net cash used in investing activities	$	(50,440	)	$	(14,597	)	$	(6,325	)
Financing Activities:
Proceeds from warrant and option exercises	$	1,202		$	1,164		$	368
Proceeds from plant term and revolving credit agreements		42,000			97,000			—
Proceeds from parent notes		13,530			53,350			—
Sale of noncontrolling interests		—			30,000			—
Proceeds from assessment financing		5,618			2,096			—
Net proceeds (payments) on Kinergy’s line of credit		(385	)		(11,141	)		43,584
Payments on plant borrowings		(59,927	)		(172,073	)		(13,833	)
Debt issuance costs		(986	)		(1,960	)		—
Preferred stock dividend payments		(1,265	)		(1,269	)		(1,265	)
Payments on capital leases		(626	)		(7,089	)		(5,059	)
Net cash provided by (used in) financing activities	$	(839	)	$	(9,922	)	$	23,795
Net increase (decrease) in cash and cash equivalents		(14,770	)		12,709			(10,523	)
Cash and cash equivalents at beginning of period		64,259			51,550			62,073
Cash and cash equivalents at end of period	$	49,489		$	64,259		$	51,550

The accompanying notes are an integral part of these consolidated financial statements.

F-10

PACIFIC ETHANOL, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

	For the Years Ended December 31,
	2017		2016		2015
Supplemental Information:
Interest paid	$	11,133	$	11,168	$	11,685
Income tax refunds	$	5,614	$	4,784	$	5,710
Noncash financing and investing activities:
Accrued payment for ownership positions of PE Op Co.	$	—	$	—	$	3,828
Capital leases added to plant and equipment	$	180	$	—	$	1,864
Reclass of warrant liability to equity upon exercises	$	178	$	179	$	72
Contribution of property and equipment for noncontrolling interest (see Note 2)	$	—	$	16,500	$	—
Debt issued in ICP acquisition (see Note 2)	$	46,927	$	—	$	—
Common stock issued in PE Central acquisition (see Note 2)	$	—	$	—	$	174,573

The accompanying notes are an integral part of these consolidated financial statements.

F-11

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. ORGANIZATION AND SIGNIFICANT ACCOUNTING POLICIES.

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”) and PE Op Co., a Delaware corporation (“PE Op Co.”).

The Company’s acquisition of Aventine Renewable Energy Holdings, Inc. (now, Pacific Ethanol Central, LLC, a Delaware limited liability company, “PE Central”) was consummated on July 1, 2015, and as a result, the Company’s consolidated financial statements include the results of PE Central only as of and for the years ended December 31, 2017 and 2016 and for the six months ended December 31, 2015.

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, the Company owned 73.93% of Pacific Aurora and ACEC owned 26.07% of Pacific Aurora as of December 31, 2017 and 2016. Further, the Company has consolidated 100% of the results of Pacific Aurora and recorded ACEC’s 26.07% equity interest as noncontrolling interests in the accompanying financial statements for the year ended December 31, 2017 and for the period December 15, 2016 through December 31, 2016.

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 only for the period from July 3, 2017 through December 31, 2017.

The Company is a leading producer and marketer of low-carbon renewable fuels in the United States. 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.

With the addition of four Midwestern ethanol plants in July 2015 as a result of the Company’s acquisition of PE Central and the addition of ICP’s plant in July 2017, the Company now has a combined production capacity of 605 million gallons per year, markets, on an annualized basis, nearly 1.0 billion gallons of ethanol and specialty alcohols, and produces, on an annualized basis, over 3.0 million tons of co-products on a dry matter basis, 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 allows for greater access to international markets.

 F-12

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

As of December 31, 2017, all nine facilities were operating. As market conditions change, the Company may increase, decrease or idle production at one or more operational facilities or resume operations at any idled facility.

Basis of Presentation – The consolidated financial statements and related notes have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) and include the accounts of the Company. All significant intercompany accounts and transactions have been eliminated in consolidation.

Segments – A segment is a component of an enterprise whose operating results are regularly reviewed by the enterprise’s chief operating decision maker to make decisions about resources to be allocated to the segment and assess its performance, and for which discrete financial information is available. The Company determines and discloses its segments in accordance with the Financial Accounting Standards Board’s (“FASB”) Accounting Standards Codification Section 280, Segment Reporting, which defines how to determine segments. The Company reports its financial and operating performance in two reportable 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.

Cash and Cash Equivalents – The Company considers all highly-liquid investments with an original maturity of three months or less to be cash equivalents. The Company maintains its accounts at several financial institutions. These cash balances regularly exceed amounts insured by the Federal Deposit Insurance Corporation, however, the Company does not believe it is exposed to any significant credit risk on these balances.

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. Due to a limited number of ethanol customers, the Company had significant concentrations of credit risk from sales of ethanol as of December 31, 2017 and 2016, as described below.

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 $64,501,000 and $64,853,000 at December 31, 2017 and 2016, respectively, were used as collateral under Kinergy’s operating line of credit. The allowance for doubtful accounts was $19,000 and $331,000 as of December 31, 2017 and 2016, respectively. The Company recorded a bad debt expense of $5,000 and $306,000 and a recovery of $354,000 for the years ended December 31, 2017, 2016 and 2015, respectively. The Company does not have any off-balance sheet credit exposure related to its customers.

 F-13

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Concentration Risks – Credit risk represents the accounting loss that would be recognized at the reporting date if counterparties failed completely to perform as contracted. Concentrations of credit risk, whether on- or off-balance sheet, that arise from financial instruments exist for groups of customers or counterparties when they have similar economic characteristics that would cause their ability to meet contractual obligations to be similarly affected by changes in economic or other conditions described below. Financial instruments that subject the Company to credit risk consist of cash balances maintained in excess of federal depository insurance limits and accounts receivable which have no collateral or security. The Company has not experienced any significant losses in such accounts and believes that it is not exposed to any significant risk of loss of cash.

The Company sells fuel-grade ethanol to gasoline refining and distribution companies. The Company sold ethanol to customers representing 10% or more of the Company’s total net sales, as follows.

	Years Ended December 31,
	2017			2016			2015
Customer A		16	%		17	%		12	%
Customer B		11	%		12	%		15	%
Customer C		6	%		6	%		12	%

The Company had accounts receivable due from these customers totaling $21,584,000 and $21,274,000, representing 27% and 25% of total accounts receivable, as of December 31, 2017 and 2016, respectively.

The Company purchases corn, its largest cost component in producing ethanol, from its suppliers. The Company purchased corn from suppliers representing 10% or more of the Company’s total corn purchases, as follows:

	Years Ended December 31,
	2017			2016			2015
Supplier A		14	%		13	%		19	%
Supplier B		13	%		4	%		—	%
Supplier C		10	%		8	%		9	%
Supplier D		9	%		13	%		13	%

Approximately 32% of the Company’s employees are covered by a collective bargaining agreement.

 F-14

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Inventories – Inventories consisted primarily of bulk ethanol, specialty alcohols, corn, co-products, low-carbon and Renewable Identification Number (“RIN”) credits and unleaded fuel, and are valued at the lower-of-cost-or-net realizable value, with cost determined on a first-in, first-out basis. Inventory is net of a $2.7 million valuation adjustment as of December 31, 2017. Inventory balances consisted of the following (in thousands):

	December 31,
	2017		2016
Finished goods	$	35,652	$	33,773
Work in progress		8,807		7,092
Raw materials		7,601		6,571
Low-carbon and RIN credits		7,952		10,926
Other		1,538		1,708
Total	$	61,550	$	60,070

Property and Equipment – Property and equipment are stated at cost. Depreciation is computed using the straight-line method over the following estimated useful lives:

Buildings	40 years
Facilities and plant equipment	10 – 25 years
Other equipment, vehicles and furniture	5 – 10 years

The cost of normal maintenance and repairs is charged to operations as incurred. Significant capital expenditures that increase the life of an asset are capitalized and depreciated over the estimated remaining useful life of the asset. The cost of property and equipment sold, or otherwise disposed of, and the related accumulated depreciation or amortization are removed from the accounts, and any resulting gains or losses are reflected in current operations.

Intangible Asset – The Company assesses indefinite-lived intangible assets for impairment annually, or more frequently if circumstances indicate impairment may have occurred. If the carrying value of an indefinite-lived intangible asset exceeds its fair value, an impairment loss is recognized in an amount equal to that excess. If the Company determines that an impairment charge is needed, the charge will be recorded as an asset impairment in the consolidated statements of operations.

Derivative Instruments and Hedging Activities – Derivative transactions, which can include exchange-traded forward contracts and futures positions on the New York Mercantile Exchange or the Chicago Board of Trade, are recorded on the balance sheet as assets and liabilities based on the derivative’s fair value. Changes in the fair value of derivative contracts are recognized currently in income unless specific hedge accounting criteria are met. If derivatives meet those criteria, and hedge accounting is elected, effective gains and losses are deferred in accumulated other comprehensive income (loss) and later recorded together with the hedged item in consolidated income (loss). For derivatives designated as a cash flow hedge, the Company formally documents the hedge and assesses the effectiveness with associated transactions. The Company has designated and documented contracts for the physical delivery of commodity products to and from counterparties as normal purchases and normal sales.

Revenue Recognition – The Company recognizes revenue when it is realized or realizable and earned. The Company considers revenue realized or realizable and earned when there is persuasive evidence of an arrangement, delivery has occurred, the sales price is fixed or determinable, and collection is reasonably assured. The Company derives revenue primarily from sales of ethanol and related co-products. The Company recognizes revenue when title transfers to its customers, which is generally upon the delivery of these products to a customer’s designated location. These deliveries are made in accordance with sales commitments and related sales orders entered into either verbally or in writing with customers. The sales commitments and related sales orders provide quantities, pricing and conditions of sales. In this regard, the Company engages in three basic types of revenue generating transactions:

● As a producer. Sales as a producer consist of sales of the Company’s inventory produced at its plants.

 F-15

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

● As a merchant. Sales as a merchant consist of sales to customers through purchases from third-party suppliers in which the Company may or may not obtain physical control of the ethanol, in which shipments are directed from the Company’s suppliers to its terminals or direct to its customers but for which the Company accepts the risk of loss in the transactions.

● As an agent. Sales as an agent consist of sales to customers through purchases from third-party suppliers in which the risks and rewards of inventory ownership remain with third-party suppliers and the Company receives a predetermined service fee under these transactions.

Revenue from sales of third-party ethanol is recorded net of costs when the Company is acting as an agent between a customer and a supplier and gross when the Company is a principal to the transaction. The Company recorded $1,663,000, $1,604,000 and $1,510,000 in net sales when acting as an agent for the years ended December 31, 2017, 2016 and 2015, respectively. Several factors are considered to determine whether the Company is acting as an agent or principal, most notably whether the Company is the primary obligor to the customer and whether the Company has inventory risk and related risk of loss or whether the Company adds meaningful value to the supplier’s product or service. Consideration is also given to whether the Company has latitude in establishing the sales price or has credit risk, or both. When the Company acts as an agent, it recognizes revenue on a net basis or recognizes its predetermined fees and any associated freight, based upon the amount of net revenues retained in excess of amounts paid to suppliers.

The Company records revenues based upon the gross amounts billed to its customers in transactions where the Company acts as a producer or a merchant and obtains title to ethanol and therefore owns the product and any related, unmitigated inventory risk for the ethanol, regardless of whether the Company actually obtains physical control of the product.

Shipping and Handling Costs – Shipping and handling costs are classified as a component of cost of goods sold in the accompanying consolidated statements of operations.

Selling Costs – Selling costs associated with the Company’s product sales are classified as a component of selling, general and administrative expenses in the accompanying consolidated statements of operations.

Stock-Based Compensation – The Company accounts for the cost of employee services received in exchange for the award of equity instruments based on the fair value of the award, determined on the date of grant. The expense is recognized over the period during which an employee is required to provide services in exchange for the award. The Company accounts for forfeitures as they occur. The Company recognizes stock-based compensation expense as a component of selling, general and administrative expenses in the consolidated statements of operations.

 F-16

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Impairment of Long-Lived Assets – The Company assesses the impairment of long-lived assets, including property and equipment, internally developed software and purchased intangibles subject to amortization, when events or changes in circumstances indicate that the fair value of assets could be less than their net book value. In such event, the Company assesses long-lived assets for impairment by first determining the forecasted, undiscounted cash flows the asset group is expected to generate plus the net proceeds expected from the sale of the asset group. If this amount is less than the carrying value of the asset, the Company will then determine the fair value of the asset group. An impairment loss would be recognized when the fair value is less than the related asset group’s net book value, and an impairment expense would be recorded in the amount of the difference. Forecasts of future cash flows are judgments based on the Company’s experience and knowledge of its operations and the industries in which it operates. These forecasts could be significantly affected by future changes in market conditions, the economic environment, including inflation, and purchasing decisions of the Company’s customers.

Deferred Financing Costs – Deferred financing costs are costs incurred to obtain debt financing, including all related fees, and are amortized as interest expense over the term of the related financing using the straight-line method, which approximates the interest rate method. Amortization of deferred financing costs was $503,000, $137,000 and $272,000 for the years ended December 31, 2017, 2016 and 2015, respectively. Unamortized deferred financing costs were approximately $1,925,000 and $1,708,000 as of December 31, 2017 and 2016, respectively, and are recorded net of long-term debt in the consolidated balance sheets.

Provision for Income Taxes – Income taxes are accounted for under the asset and liability approach, where deferred tax assets and liabilities are determined based on differences between financial reporting and tax basis of assets and liabilities, and are measured using enacted tax rates and laws that are expected to be in effect when the differences reverse. Valuation allowances are established when necessary to reduce deferred tax assets to the amounts expected to be realized.

The Company accounts for uncertainty in income taxes using a two-step approach to recognizing and measuring uncertain tax positions. The first step is to evaluate the tax position for recognition by determining whether it is more likely than not that the position will be sustained on audit, including resolution of related appeals or litigation processes, if any. The second step is to measure the tax benefit as the largest amount which is more than 50% likely of being realized upon ultimate settlement. An uncertain tax position is considered effectively settled on completion of an examination by a taxing authority if certain other conditions are satisfied. Should the Company incur interest and penalties relating to tax uncertainties, such amounts would be classified as a component of interest expense and other income (expense), net, respectively. Deferred tax assets and liabilities are classified as noncurrent in the Company’s consolidated balance sheets.

The Company files a consolidated federal income tax return. This return includes all wholly-owned subsidiaries as well as the Company’s pro-rata share of taxable income from pass-through entities in which the Company owns less than 100%. State tax returns are filed on a consolidated, combined or separate basis depending on the applicable laws relating to the Company and its subsidiaries.

Income (Loss) Per Share – Basic income (loss) per share is computed on the basis of the weighted-average number of shares of common stock outstanding during the period. Preferred dividends are deducted from net income (loss) attributed to Pacific Ethanol, Inc. and are considered in the calculation of income (loss) available to common stockholders in computing basic income (loss) per share. Common stock equivalents to the preferred stock are considered participating securities and are also included in this calculation when dilutive.

 F-17

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

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

	Year Ended December 31, 2017
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(34,964	)
Less: Preferred stock dividends		(1,265	)
Basic and Diluted loss per share:
Loss available to common stockholders	$	(36,229	)		42,745	$	(0.85	)

	Year Ended December 31, 2016
	Income Numerator			Shares Denominator		Per-Share Amount
Net income attributed to Pacific Ethanol	$	1,419
Less: Preferred stock dividends		(1,269	)
Less: Allocated to participating securities		(2	)
Basic income per share:
Income available to common stockholders	$	148			42,182	$	0.00
Add: Options		—			69
Diluted income per share:
Income available to common stockholders	$	148			42,251	$	0.00

	Year Ended December 31, 2015
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(18,786	)
Less: Preferred stock dividends		(1,265	)
Basic and Diluted loss per share:
Loss available to common stockholders	$	(20,051	)		33,173	$	(0.60	)

There were an aggregate of 719,000, 704,000 and 817,000 potentially dilutive shares from convertible securities outstanding as of December 31, 2017, 2016 and 2015, respectively. These convertible securities were not considered in calculating diluted income (loss) per common share for the years ended December 31, 2017, 2016 and 2015 as their effect would be anti-dilutive.

Financial Instruments – The carrying values of cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities 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.

 F-18

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Employment-related Benefits – Employment-related benefits associated with pensions and postretirement health care are expensed based on actuarial analysis. The recognition of expense is affected by estimates made by management, such as discount rates used to value certain liabilities, investment rates of return on plan assets, increases in future wage amounts and future health care costs. Discount rates are determined based on a spot yield curve that includes bonds with maturities that match expected benefit payments under the plan.

Estimates and Assumptions – The preparation of the consolidated financial statements in conformity with GAAP 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 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.

Subsequent Events – Management evaluates, as of each reporting period, events or transactions that occur after the balance sheet date through the date that the financial statements are issued for either disclosure or adjustment to the consolidated financial results.

Reclassifications – Certain prior year amounts have been reclassified to conform to the current presentation, including the classification of cash collateral balances held with commodity brokers and the classification of external selling costs with respect to the Company’s co-product sales. Cash collateral balances of $4,331,000 as of December 31, 2016 were reclassified from cash and cash equivalents to other current assets on the consolidated balance sheet. External selling costs for the years ended December 31, 2016 and 2015 of $2,526,000 and $2,956,000, respectively, were reclassified from cost of goods sold to selling, general and administrative expenses on the consolidated statements of operations. Such reclassifications had no effect on the consolidated net income (loss), working capital or stockholder’s equity reported in the consolidated statements of operations and consolidated balance sheets.

Recent Accounting Pronouncements – In May 2014, the FASB issued new guidance on the recognition of revenue (“ASC 606”). 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.

 F-19

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

The Company adopted ASC 606 on January 1, 2018. The Company has completed its evaluation of the new requirements under ASC 606 on each of its major revenue types. The Company’s 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, however, will expand certain disclosures of its revenue streams. The Company will adopt the new guidance using the modified retrospective transition method.

In February 2016, the 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, 2018, including interim periods within those fiscal years. The Company expects that upon adoption of this accounting standard, right of use assets and lease obligations will be recognized in its consolidated balance sheets in amounts that will be material.

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.

2. PACIFIC ETHANOL PLANTS.

Illinois Corn Processing

On July 3, 2017, the Company purchased 100% of the equity interests of ICP from ICP’s owners, Illinois Corn Processing Holdings Inc. (“ICPH”) and MGPI Processing, Inc. (together with ICPH, the “Sellers”). At the closing, ICP became an indirect wholly-owned subsidiary of the Company.

Upon closing, the Company (i) paid to the Sellers $30.0 million in cash, and (ii) issued to the Sellers secured promissory notes in the aggregate principal amount of approximately $46.9 million (the “Seller Notes”). The Seller Notes were secured by a first priority lien on ICP’s assets 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 Company’s facility in Pekin, Illinois and is located on the Illinois River. ICP produces fuel-grade ethanol, beverage and industrial-grade alcohol, dry distillers grain and corn oil. The facility has direct access to end-markets via barge, rail and truck, and expands the Company’s domestic and international distribution channels. ICP is reflected in the results of the Company’s production segment.

 F-20

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

The Company has recognized the following allocation of the purchase price at fair values. No intangible assets or liabilities have been recognized due to ICP’s contracts being materially close to market prices. The Company’s purchase price consideration allocation is as follows (in thousands):

Cash and equivalents	$	426
Accounts receivable		11,636
Inventories		9,227
Other current assets		1,560
Total current assets		22,849
Property and equipment		61,128
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.

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

	Years Ended December 31,
	2017			2016
Revenues – pro forma	$	1,710,317		$	1,802,159
Consolidated net income (loss) – pro forma	$	(42,589	)	$	8,329
Diluted net income (loss) per share – pro forma	$	(0.95	)	$	0.16
Diluted weighted-average shares – pro forma		42,745			42,251

For the year ended December 31, 2017, ICP contributed $75.9 million in net revenues and $3.7 million in pre-tax income. For the year ended December 31, 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.

 F-21

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

PE Central

On July 1, 2015, the Company acquired 100% of PE Central and its plants, through a stock-for-stock merger. The Company issued an aggregate of 17.8 million shares of common stock and non-voting common stock for 100% of the outstanding shares of common stock of PE Central. The common stock and non-voting common stock issued as consideration had an aggregate fair value of $174.6 million, based on the closing market price of the Company’s common stock on the acquisition date.

The Company believes the acquisition of PE Central resulted in a number of synergies and strategic advantages. The Company believes the acquisition spread commodity and basis price risks across diverse markets and products, assisting in its efforts to optimize margin management; improved its hedging opportunities with a greater correlation to the liquid physical and paper markets in Chicago; and increased its flexibility and alternatives in feedstock procurement for its Midwestern and Western production facilities. The acquisition also expanded the Company’s marketing reach into new markets and extended its mix of co-products. The Company believes the acquisition enabled it to have deeper market insight and engagement in major ethanol and feed markets outside the Western United States, thereby improving pricing opportunities; allowed the Company to establish access to markets in 48 states for ethanol sales and access many markets with ethanol and co-product sales reaching domestic and international customers; and enabled it to use its more diverse mix of co-products to generate strong co-product returns.

The Company recognized the following allocation of the purchase price at fair values. The Company included in the following allocation its estimated fair values for certain operating lease agreements and open commitments. The fair-value determination of long-term debt was based on the interest rate environment at the acquisition date. Based on the final allocation, the Company recorded an immaterial bargain purchase gain on the acquisition.

The purchase price consideration allocation is as follows (in thousands):

Cash and equivalents	$	18,756
Accounts receivable		10,430
Inventories		29,483
Other current assets		8,304
Total current assets		66,973
Property and equipment		312,781
Net deferred tax assets		12,159
Other assets		750
Total assets acquired	$	392,663
Accounts payable and accrued liabilities	$	27,780
Long-term debt - revolvers		13,721
Long-term debt - term debt		142,744
Pension plan liabilities		8,518
Other non-current liabilities		25,327
Total liabilities assumed	$	218,090
Net assets acquired	$	174,573

 F-22

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

The contractual amount due on the accounts receivable acquired was $10.8 million, of which $0.4 million is expected to be uncollectible. In accounting for the acquisition, the Company recorded $3.7 million in other noncurrent liabilities as a litigation contingency related to certain litigation matters for amounts that were probable and estimable as of the acquisition date. Subsequent to the acquisition date, the Company settled for $2.1 million certain litigation for which liabilities were recorded. Certain of these settlements were made after the measurement period, and as such the Company recorded a gain of $1.1 million for the year ended December 31, 2016 in selling, general and administrative expenses in the accompanying consolidated statements of operations. See Note 14 for further details.

The following table presents unaudited pro forma financial information for the year ended December 31, 2015, assuming the acquisition occurred on January 1, 2014 (in thousands except per share data).

Net sales – pro forma	$	1,484,676
Cost of goods sold – pro forma	$	1,469,512
Selling, general and administrative expenses – pro forma	$	34,735
Net loss – pro forma	$	(34,136	)
Diluted net loss per share – pro forma	$	(0.81	)
Diluted weighted-average shares – pro forma		42,053

The effects of the initial step-up of inventories and open contracts in the aggregate of $8.7 million recorded during 2015 were excluded in the above amounts for 2015 as if the acquisition had occurred on January 1, 2014. For the six months ended December 31, 2015, PE Central contributed $299.0 million in net sales and $16.3 million in pre-tax loss. For the year ended December 31, 2017, PE Central contributed $610.5 million in net sales and $8.4 million in pre-tax loss. For the year ended December 31, 2016, PE Central contributed $650.1 million in net sales and $2.1 million in pre-tax income. For the year ended December 31, 2015, the Company recorded approximately $1.4 million in costs associated with the PE Central acquisition. These costs are reflected in selling, general and administrative expenses on the Company’s consolidated statements of operations, but were excluded from the amounts above.

Pacific Aurora

On December 15, 2016, PE Central closed on an agreement with ACEC under which (i) PE Central contributed to Pacific Aurora 100% of the equity interests of its wholly-owned subsidiaries, Pacific Ethanol Aurora East, LLC (“AE”) and Pacific Ethanol Aurora West, LLC (“AW”), which owned the Company’s Aurora East and Aurora West ethanol plants, respectively, in exchange for an 88.15% ownership interest in Pacific Aurora, and (ii) ACEC contributed to Pacific Aurora its grain elevator adjacent to the Aurora East and Aurora West properties and related grain handling assets, including the outer rail loop and the real property on which they are located, in exchange for an 11.85% ownership interest in Pacific Aurora. On December 15, 2016, concurrent with the closing of the contribution transaction, PE Central sold a 14.22% ownership interest in Pacific Aurora to ACEC for $30.0 million in cash.

Following the closing of these transactions, PE Central owned 73.93% of Pacific Aurora and ACEC owned 26.07% of Pacific Aurora.

 F-23

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

The Company has consolidated 100% of the results of Pacific Aurora and recorded the amount attributed to ACEC as noncontrolling interests under the voting rights model. Since the Company had control of AE and AW prior to forming Pacific Aurora, there was no gain or loss recorded on the contribution and ultimate sale of a portion of the Company’s interests in Pacific Aurora. ACEC contributed $16.5 million in assets at fair market value and paid $30.0 million in cash for its additional ownership interests. A noncontrolling interest was recognized to reflect ACEC’s proportional ownership interest multiplied by the book value of Pacific Aurora’s net assets. As a result, the Company recorded $16.2 million as additional paid-in capital attributed to the difference between Pacific Aurora’s book value and the contribution and sale.

On December 15, 2016, the Company entered into a working capital maintenance agreement with Pacific Aurora’s lender, under which the Company agreed to contribute capital to Pacific Aurora from time to time, if needed, in an amount up to $15.0 million to ensure that Pacific Aurora maintains the minimum working capital thresholds required in its credit agreement as further discussed in Note 9. In addition, dividends from Pacific Aurora to its members are limited to 40% of Pacific Aurora’s annual net income.

The carrying values and classification of assets and liabilities of Pacific Aurora as of December 31, 2016 were as follows (in thousands):

Cash and equivalents	$	1,453
Accounts receivable		16,804
Inventories		3,837
Other current assets		77
Total current assets		22,171
Property and equipment		115,759
Other assets		1,387
Total assets	$	139,317
Accounts payable and accrued liabilities	$	20,152
Other current liabilities		2,045
Long-term debt outstanding, net		621
Total liabilities	$	22,818

PE OP Co.

Prior to May 2015, the Company held a 96% ownership in PE Op Co. In May 2015, it purchased the remaining 4% ownership interest in PE Op Co. for $6.0 million in cash, bringing its ownership of PE Op Co. to 100%.

Because the Company had a controlling financial interest in PE Op Co. at the time of this purchase, it did not record any gains or losses, but instead reduced the amount of noncontrolling interest on the consolidated balance sheets by an aggregate of $4.4 million and recorded the difference of $0.6 million and for the year ended December 31, 2015, which represented the fair value of this purchase above the price paid by the Company, to additional paid-in capital on the consolidated balance sheet.

 F-24

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

3. INTERCOMPANY AGREEMENTS.

The Company, directly or through one of its subsidiaries, has entered into the following management and marketing agreements:

Affiliate Management Agreement – Pacific Ethanol entered into an Affiliate Management Agreement (“AMA”) with its operating subsidiaries, namely Kinergy, PAP, the Pacific Ethanol West Plants and the Pacific Ethanol Central Plants, effective July 1, 2015, with Pacific Aurora, effective December 15, 2016, and with ICP, effective July 1, 2017, under which Pacific Ethanol agreed to provide operational and administrative and staff support services. These services generally include, but are not limited to, administering the subsidiaries’ compliance with their credit agreements and performing billing, collection, record keeping and other administrative and ministerial tasks. Pacific Ethanol agreed to supply all labor and personnel required to perform its services under the AMA, including the labor and personnel required to operate and maintain the production facilities and marketing activities. These services are billed at a predetermined amount per subsidiary each month plus out of pocket costs such as employee wages and benefits.

The AMAs have an initial term of one year and automatic successive one year renewal periods. Pacific Ethanol may terminate the AMA, and any subsidiary may terminate the AMA, at any time by providing at least 90 days prior notice of such termination.

Pacific Ethanol recorded revenues of approximately $11,904,000, $12,968,000 and $9,857,000 related to the AMAs in place for the years ended December 31, 2017, 2016 and 2015, respectively. These amounts have been eliminated upon consolidation.

Ethanol Marketing Agreements – Kinergy entered into separate ethanol marketing agreements with each of the Company’s nine plants, which granted it the exclusive right to purchase, market and sell the ethanol produced at those facilities. Under the terms of the ethanol marketing agreements, within ten days after delivering ethanol to Kinergy, an amount is paid to Kinergy equal to (i) the estimated purchase price payable by the third-party purchaser of the ethanol, minus (ii) the estimated amount of transportation costs to be incurred, minus (iii) the estimated incentive fee payable to Kinergy, which equals 1% of the aggregate third-party purchase price, provided that the marketing fee shall not be less than $0.015 per gallon and not more than $0.0225 per gallon. Each of the ethanol marketing agreements had an initial term of one year and successive one year renewal periods at the option of the individual plant.

Kinergy recorded revenues of approximately $8,464,000, $8,029,000 and $5,262,000 related to the ethanol marketing agreements for the years ended December 31, 2017, 2016 and 2015, respectively. These amounts have been eliminated upon consolidation.

Corn Procurement and Handling Agreements – PAP entered into separate corn procurement and handling agreements with each of the Company’s plants, with the exception of the Pacific Aurora facilities, which terminated its agreements with PAP on December 15, 2016. Under the terms of the corn procurement and handling agreements, each facility appointed PAP as its exclusive agent to solicit, negotiate, enter into and administer, on its behalf, corn supply arrangements to procure the corn necessary to operate its facility. PAP also provides grain handling services including, but not limited to, receiving, unloading and conveying corn into the facility’s storage and, in the case of whole corn delivered, processing and hammering the whole corn.

 F-25

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Under these agreements, PAP receives a fee of $0.045 per bushel of corn delivered to each facility as consideration for its procurement and handling services, payable monthly. Effective December 15, 2016, this fee is $0.03 per bushel of corn. Each corn procurement and handling agreement had an initial term of one year and successive one year renewal periods at the option of the individual plant. PAP recorded revenues of approximately $4,245,000, $4,386,000 and $2,910,000 related to the corn procurement and handling agreements for the years ended December 31, 2017, 2016 and 2015, respectively. These amounts have been eliminated upon consolidation.

Effective December 15, 2016, each Pacific Aurora facility entered into a new grain procurement agreement with ACEC. Under this agreement, ACEC receives a fee of $0.03 per bushel of corn delivered to each facility as consideration for its procurement and handling services, payable monthly. The grain procurement agreement has an initial term of one year and successive one year renewal periods at the option of the individual plant. Pacific Aurora recorded expenses of approximately $816,000 and $107,000 for the year ended December 31, 2017 and the period from December 15, 2016 to December 31, 2016, respectively. These amounts have not been eliminated upon consolidation as they are with a related but unconsolidated third-party.

Distillers Grains Marketing Agreements – PAP entered into separate distillers grains marketing agreements with each of the Company’s plants, which grant PAP the exclusive right to market, purchase and sell the various co-products produced at each facility. Under the terms of the distillers grains marketing agreements, within ten days after a plant delivers co-products to PAP, the plant is paid an amount equal to (i) the estimated purchase price payable by the third-party purchaser of the co-products, minus (ii) the estimated amount of transportation costs to be incurred, minus (iii) the estimated amount of fees and taxes payable to governmental authorities in connection with the tonnage of the co-products produced or marketed, minus (iv) the estimated incentive fee payable to the Company, which equals (a) 5% of the aggregate third-party purchase price for wet corn gluten feed, wet distillers grains, corn condensed distillers solubles and distillers grains with solubles, or (b) 1% of the aggregate third-party purchase price for corn gluten meal, dry corn gluten feed, dry distillers grains, corn germ and corn oil. Each distillers grains marketing agreement had an initial term of one year and successive one year renewal periods at the option of the individual plant.

PAP recorded revenues of approximately $6,020,000, $6,047,000 and $4,438,000 related to the distillers grains marketing agreements for the years ended December 31, 2017, 2016 and 2015, respectively. These amounts have been eliminated upon consolidation.

4. 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.

Income before provision for income taxes includes management fees charged by Pacific Ethanol to the segment. The production segment incurred $9,744,000, $9,968,000 and $5,957,000 in management fees for the years ended December 31, 2017, 2016 and 2015, respectively. The marketing and distribution segment incurred $2,160,000, $3,000,000 and $3,900,000 in management fees for the years ended December 31, 2017, 2016 and 2015, respectively. Corporate activities include selling, general and administrative expenses, consisting primarily of corporate employee compensation, professional fees and overhead costs not directly related to a specific operating segment.

 F-26

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

During the normal course of business, the segments do business with each other. The preponderance of this activity occurs when the Company’s marketing segment markets ethanol produced by the production segment for a marketing fee, as discussed in Note 3. These intersegment activities are considered arms’-length transactions. Consequently, although these transactions impact segment performance, they do not impact the Company’s consolidated results since all revenues and corresponding costs are eliminated in consolidation.

Capital expenditures are substantially all incurred at the Company’s production segment.

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

	Years Ended December 31,
	2017			2016			2015
Net Sales
Production:
Net sales to external customers	$	1,102,722		$	1,045,807		$	710,201
Intersegment net sales		1,898			1,169			—
Total production segment net sales		1,104,620			1,046,976			710,201
Marketing and distribution:
Net sales to external customers		529,533			578,951			480,975
Intersegment net sales		8,464			8,029			5,262
Total marketing and distribution net sales		537,997			586,980			486,237
Intersegment eliminations		(10,362	)		(9,198	)		(5,262	)
Net sales as reported	$	1,632,255		$	1,624,758		$	1,191,176
Cost of goods sold:
Production	$	1,098,977		$	1,015,655		$	716,877
Marketing and distribution		535,032			575,921			476,410
Intersegment eliminations		(7,685	)		(21,176	)		(12,477	)
Cost of goods sold as reported	$	1,626,324		$	1,570,400		$	1,180,810
Income (loss) before provision for income taxes:
Production	$	(27,458	)	$	(6,882	)	$	(32,723	)
Marketing and distribution		(2,463	)		4,517			3,200
Corporate activities		(8,474	)		2,910			616
	$	(38,395	)	$	545		$	(28,907	)
Depreciation and amortization:
Production	$	37,637		$	34,528		$	23,091
Marketing and distribution		—			3			151
Corporate activities		1,014			910			390
	$	38,651		$	35,441		$	23,632
Interest expense:
Production	$	5,887		$	20,794		$	11,969
Marketing and distribution		1,271			1,404			625
Corporate activities		5,780			208			—
	$	12,938		$	22,406		$	12,594

 F-27

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

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

	December 31,
	2017		2016
Total assets:
Production	$	583,696	$	542,688
Marketing and distribution		127,242		146,356
Corporate assets		9,358		19,194
	$	720,296	$	708,238

5. PROPERTY AND EQUIPMENT.

Property and equipment consisted of the following (in thousands):

	December 31,
	2017			2016
Facilities and plant equipment	$	601,156		$	530,735
Land		8,970			7,771
Other equipment, vehicles and furniture		10,189			9,714
Construction in progress		38,041			29,393
		658,356			577,613
Accumulated depreciation		(150,004	)		(112,423	)
	$	508,352		$	465,190

Depreciation expense was $38,651,000, $35,441,000 and $23,632,000 for the years ended December 31, 2017, 2016 and 2015, respectively. For the year ended December 31, 2015, the Company recorded an impairment charge of $1,970,000 related to the abandonment of certain accounting and information technology systems following the integration of its PE Central facilities.

 F-28

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

For the year ended December 31, 2017 and 2016, the Company capitalized interest of $822,000 and $1,307,000, respectively, related to its capital investment activities.

6. INTANGIBLE ASSET.

The Company recorded a tradename valued at $2,678,000 in 2006 as part of its acquisition of Kinergy. The Company determined that the Kinergy tradename has an indefinite life and, therefore, rather than being amortized, will be tested annually for impairment. The Company did not record any impairment of the Kinergy tradename for the years ended December 31, 2017, 2016 and 2015.

7. 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 in order 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 years ended December 31, 2017, 2016 and 2015, 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 net losses of $2,077,000, $1,984,000 and $542,000 as the change in the fair value of these contracts for the years ended December 31, 2017, 2016 and 2015, respectively.

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

	As of December 31, 2017
	Assets			Liabilities
Type of Instrument	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Cash collateral balance	Other current assets	$	3,813
Commodity contracts	Derivative assets	$	998	Derivative liabilities	$	2,307

 F-29

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

	As of December 31, 2016
	Assets			Liabilities
Type of Instrument	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Cash collateral balance	Other current assets	$	4,331
Commodity contracts	Derivative assets	$	978	Derivative liabilities	$	4,115

The above amounts represent the gross balances of the contracts, however, the Company does have the right of offset with each of its derivative brokers.

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)
		For the Years Ended December 31,
Type of Instrument	Statements of Operations Location	2017			2016		2015
Commodity contracts	Cost of goods sold	$	(4,165	)	$	1,386	$	(338	)
		$	(4,165	)	$	1,386	$	(338	)

		Unrealized Gains (Losses)
		For the Years Ended December 31,
Type of Instrument	Statements of Operations Location	2017		2016			2015
Commodity contracts	Cost of goods sold	$	2,088	$	(3,370	)	$	(204	)
		$	2,088	$	(3,370	)	$	(204	)

 F-30

PACIFIC ETHANOL, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

8. DEBT.

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

	December 31, 2017			December 31, 2016
Kinergy line of credit	$	49,477		$	49,862
Pekin term loan		53,500			64,000
Pekin revolving loan		32,000			32,000
ICP term loan		22,500			—
ICP revolving loan		18,000			—
Pacific Aurora line of credit		—			1,000
Parent notes payable		68,948			55,000
		244,425			201,862
Less unamortized debt discount		(1,409	)		(1,626	)
Less unamortized debt financing costs		(1,925	)		(1,708	)
Less short-term portion		(20,000	)		(10,500	)
Long-term debt	$	221,091		$	188,028

Kinergy Line of Credit – Kinergy has an operating line of credit for an aggregate amount of up to $100,000,000. The line of credit matures on August 2, 2022. The credit facility is based on Kinergy’s eligible accounts receivable and inventory levels, subject to certain concentration reserves. The credit facility is subject to certain other sublimits, including inventory loan limits. Interest accrues under the line of credit at a rate equal to (i) the three-month London Interbank Offered Rate (“LIBOR”), plus (ii) a specified applicable margin ranging between 1.50% and 2.00%. The applicable margin was 1.75%, for a total rate of 3.44% at December 31, 2017. The credit facility’s monthly unused line fee is an annual rate equal to 0.25% to 0.375% depending on the average daily principal balance during the immediately preceding month. Payments that may be made by Kinergy to the Company as reimbursement for management and other services provided by the Company to Kinergy are limited under the terms of the credit facility to $1,500,000 per fiscal quarter.

The credit facility also includes the accounts receivable of PAP as additional collateral. Payments that may be made by PAP to the Company as reimbursement for management and other services provided by the Company to PAP are limited under the terms of the credit facility to $500,000 per fiscal quarter.

If Kinergy and PAP’s monthly excess borrowing availability falls below certain thresholds, they are collectively required to maintain a fixed-charge coverage ratio (calculated as a twelve-month rolling EBITDA divided by the sum of interest expense, capital expenditures, 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 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. Pacific Ethanol has guaranteed all of Kinergy’s obligations under the line of credit. As of December 31, 2017, Kinergy had an available unused availability under the credit facility of $27,399,000.

F-31

PACIFIC ETHANOL, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Pekin Credit Facilities – On December 15, 2016, the Company’s wholly-owned subsidiary, Pacific Ethanol Pekin, Inc. (“Pekin”), entered into a Credit Agreement (the “Pekin Credit Agreement”) with 1^st Farm Credit Services, PCA and CoBank, ACB (“CoBank”). On December 15, 2016, under the terms of the Pekin Credit Agreement, Pekin borrowed from 1^st Farm Credit Services $64.0 million under a term loan facility that matures on August 20, 2021 (the “Pekin Term Loan”) and $32.0 million under a revolving term loan facility that matures on February 1, 2022 (the “Pekin Revolving Loan” and, together with the Pekin Term Loan, the “Pekin Credit Facility”). The Pekin Credit Facility is secured by a first-priority security interest in all of Pekin’s assets under the terms of a Security Agreement, dated December 15, 2016, by and between Pekin and CoBank (the “Pekin Security Agreement”). Interest accrues under the Pekin Credit Facility at an annual rate equal to the 30-day LIBOR plus 3.75%, payable monthly. Pekin is required to make quarterly principal payments in the amount of $3.5 million on the Pekin Term Loan beginning on May 20, 2017 and a principal payment of $4.5 million at maturity on August 20, 2021. Pekin is required to pay a monthly fee on any unused portion of the Pekin Revolving Loan at a rate of 0.75% per annum. Prepayment of the Pekin Credit Facility is subject to a prepayment penalty. Under the terms of the Pekin Credit Agreement, Pekin is required to maintain not less than $20.0 million in working capital and an annual debt coverage ratio of not less than 1.25 to 1.0. The Pekin Credit Agreement contains a variety of affirmative covenants, negative covenants and events of default.

On August 7, 2017, 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%. Pekin and its lender also agreed that 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. For the month ended January 31, 2018, Pekin was not in compliance with its working capital requirement due to larger than anticipated repair and maintenance related expenses to replace faulty equipment. Pekin has received a waiver from its lender for this noncompliance. Further, the lender decreased Pekin’s working capital covenant requirement to be $13.0 million for the month ended February 28, 2018, excluding the $3.5 million principal payment due in May 2018 from the calculation. As of the filing of this report, management believes Pekin is in compliance with its working capital requirement.

ICP Credit Facilities — On September 15, 2017, ICP, Compeer Financial, PCA (“Compeer”), and CoBank as agent, entered into a Credit Agreement (“ICP Credit Agreement”). Under the ICP Credit Agreement, Compeer 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. ICP used the proceeds of the term 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. ICP used 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 CoBank ten days prior written notice. The revolving loan requires ICP to pay CoBank 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.

F-32

PACIFIC ETHANOL, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

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 service coverage ratio of not less than 1.50 to 1.00 beginning for the year ending December 31, 2018.

Pacific Aurora Line of Credit – On December 15, 2016, Pacific Aurora entered into a credit agreement (the “Pacific Aurora Credit Agreement”) with CoBank. Under the terms of the Pacific Aurora Credit Agreement, Pacific Aurora may borrow up to $30.0 million under a revolving term loan facility from CoBank that matures on February 1, 2022 (the “Pacific Aurora Credit Facility”). The Pacific Aurora Credit Facility is secured by a first-priority security interest in all of Pacific Aurora’s assets under the terms of a Security Agreement, dated December 15, 2016, by and among Pacific Aurora and CoBank (the “Pacific Aurora Security Agreement”). Borrowing availability under the Pacific Aurora Credit Facility automatically declines by $2.5 million on the first day of each June and December beginning on June 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 Pacific Aurora Credit Facility at a rate of 0.75% per annum. Prepayment of the Pacific Aurora Credit Facility is subject to a prepayment penalty. Under the terms of the Pacific Aurora Credit Agreement, Pacific Aurora was required to maintain not less than $22.5 million in working capital through June 30, 2017, not less than $24.0 million in working capital after June 30, 2017, and an annual debt coverage ratio of not less than 1.50 to 1.00. These covenants were partially amended, as noted below.

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.

At December 31, 2017, Pacific Aurora was not in compliance with its working capital and Debt Service Coverage Ratio requirements. The Company did not utilize the credit facility in 2017 and has no plans to draw on the facility at this time, having addressed the liquidity and capital needs of Pacific Aurora through other means. Consequently, the Company is in discussions with its lender to either amend the credit facility or terminate it.

Pacific Ethanol, Inc. Notes Payable – On December 12, 2016, Pacific Ethanol entered into a Note Purchase Agreement (the “Note Purchase Agreement”) with five accredited investors. On December 15, 2016, under the terms of the Note Purchase Agreement, Pacific Ethanol sold $55.0 million in aggregate principal amount of its senior secured notes to the Investors in a private offering for aggregate gross proceeds of 97% of the principal amount of the Notes sold. On June 26, 2017, the Company entered into a second Note Purchase Agreement with five accredited investors. On June 30, 2017, under the terms of the second Note Purchase Agreement, the Company sold an additional $13.9 million in aggregate principal amount of its senior secured notes to the investors in a private offering for aggregate gross proceeds of 97% of the principal amount of the notes sold (collectively with the notes sold on December 15, 2016, the “Notes”), for a total of $68.9 million in aggregate principal amount of Notes.

F-33

PACIFIC ETHANOL, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

The Notes mature on December 15, 2019 (the “Maturity Date”). Interest on the Notes accrues at a rate equal to (i) the greater of 1% and the three-month LIBOR, plus 7.0% from the closing 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. The interest rate increases by an additional 2% per annum above the interest rate otherwise applicable upon the occurrence and during the continuance of an event of default until such event of default has been cured. Interest is payable in cash on the 15th calendar day of each March, June, September and December. Pacific Ethanol is required to pay all outstanding principal and any accrued and unpaid interest on the Notes on the Maturity Date. Pacific Ethanol may, at its option, prepay the outstanding principal amount of the Notes at any time without premium or penalty. The Notes contain a variety of events of default. The payments due under the Notes rank senior to all other indebtedness of Pacific Ethanol, other than permitted senior indebtedness. The Notes contain a variety of obligations on the part of Pacific Ethanol not to engage in certain activities, including that (i) Pacific Ethanol and certain of its subsidiaries will not incur other indebtedness, except for certain permitted indebtedness, (ii) Pacific Ethanol and certain of its subsidiaries will not redeem, repurchase or pay any dividend or distribution on their respective capital stock without the prior consent of the holders of the Notes holding 66-2/3% of the aggregate principal amount of the Notes, other than certain permitted distributions, (iii) Pacific Ethanol and certain of its subsidiaries will not sell, lease, assign, transfer or otherwise dispose of any assets of Pacific Ethanol or any such subsidiary, except for certain permitted dispositions (including the sales of inventory or receivables in the ordinary course of business), and (iv) Pacific Ethanol and certain of its subsidiaries will not issue any capital stock or membership interests for any purpose other than to pay down a portion of all of the amounts owed under the Notes and in connection with Pacific Ethanol’s stock incentive plans. The Notes are secured by a first-priority security interest in the equity interest held by Pacific Ethanol in its wholly-owned subsidiary, PE Op. Co., which indirectly owns the Company’s plants located on the West Coast.

Pacific Ethanol West Plants’ Term Debt – The Pacific Ethanol West Plants’ debt as of December 31, 2015 consisted of a $17,003,000 tranche A-1 term loan which was to mature in June 2016. On February 26, 2016, the Company retired the $17,003,000 outstanding balance by purchasing the lender’s position for cash at par without any prepayment penalty. The purchase increased the amount of the term debt held by Pacific Ethanol from $41,763,000 at December 31, 2015 to $58,766,000 at December 31, 2016 and 2017, which is eliminated upon consolidation, as the Company has no continuing obligations to any third-party lender under the credit agreements associated with this term debt.

Pacific Ethanol Central Plants’ Term Debt – On July 1, 2015, upon effectiveness of the PE Central acquisition, PE Central became a wholly-owned subsidiary of the Company and, on a consolidated basis, the combined company became obligated with respect to the Pacific Ethanol Central Plants’ term loan and revolving credit facilities. In connection with the Company’s allocation of purchase price, the debt was recorded at $142,744,000, net of a discount of $2,875,000. The term loan facility was to mature on September 24, 2017. The term loan facility was secured through a first-priority lien on substantially all of the Pacific Ethanol Central Plants’ assets.

Interest on the term loan facility accrued and could either be paid in cash at a rate of 10.5% per annum or paid in-kind at a rate of 15.0% per annum by adding such interest to the outstanding principal balance. The Company paid interest in cash for the period from July 1, 2015, the effective date of the PE Central acquisition, through December 31, 2015. During the year ended December 31, 2016, the Company elected to pay in-kind an aggregate of $9,451,000 of interest, which was added to the principal balance. As of December 15, 2016, the principal balance was $155,070,205. On December 15, 2016, the Company paid in full the outstanding principal balance and all accrued and unpaid interest. The Company did not pay any prepayment penalties. The Company fully amortized the remaining unamortized debt discount of $1,152,000 and recorded the amount in interest expense for the year ended December 31, 2016.

F-34

PACIFIC ETHANOL, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Maturities of Long-term Debt – The Company’s long-term debt matures as follows (in thousands):

December 31:
	2018	$	20,000
	2019		88,948
	2020		20,000
	2021		16,000
	2022		99,477
		$	244,425

9. PENSION PLANS.

Retirement Plan - The Company sponsors a defined benefit pension plan (the “Retirement Plan”) that is noncontributory, and covers only “grandfathered” unionized employees at its Pekin, Illinois, facility. The Company assumed the Retirement Plan as part of its acquisition of PE Central on July 1, 2015. Benefits are based on a prescribed formula based upon the employee’s years of service. Employees hired after November 1, 2010, are not eligible to participate in the Retirement Plan. The Company uses a December 31 measurement date for its Retirement Plan. The Company’s funding policy is to make the minimum annual contribution required by applicable regulations.

Information related to the Retirement Plan as of and for the years ended December 31, 2017, 2016 and 2015 is presented below (dollars in thousands):

	2017			2016			2015
Changes in plan assets:
Fair value of plan assets, beginning	$	12,423		$	12,567		$	13,180
Actual gains (losses)		1,722			523			(298	)
Benefits paid		(665	)		(667	)		(315	)
Company contributions		478			—			—
Participant contributions		—			—			—
Fair value of plan assets, ending	$	13,958		$	12,423		$	12,567
Less: projected accumulated benefit obligation	$	19,658		$	18,455		$	16,552
Funded status, (underfunded)/overfunded	$	(5,700	)	$	(6,032	)	$	(3,985	)
Amounts recognized in the consolidated balance sheets:
Other liabilities	$	(5,700	)	$	(6,032	)	$	(3,985	)
Accumulated other comprehensive loss (income)	$	726		$	1,047		$	(885	)
Components of net periodic benefit costs are as follows:
Service cost	$	391		$	223		$	211
Interest cost		750			686			338
Expected return on plan assets		(674	)		(794	)		(500	)
Net periodic benefit cost	$	467		$	115		$	49
Loss (gain) recognized in other comprehensive income (expense)	$	(321	)	$	1,932		$	(885	)
Assumptions used in computation benefit obligations:
Discount rate		3.60	%		4.15	%		4.23	%
Expected long-term return on plan assets		6.00	%		6.75	%		7.75	%
Rate of compensation increase		—			—			—

F-35

PACIFIC ETHANOL, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

The Company expects to make contributions in the year ending December 31, 2018 of approximately $1.0 million. Net periodic benefit cost for 2018 is estimated at approximately $0.3 million.

The following table summarizes the expected benefit payments for the Company’s plan for each of the next five fiscal years and in the aggregate for the five fiscal years thereafter (in thousands):

December 31:
	2018	$	730
	2019		740
	2020		780
	2021		790
	2022		830
	2023-27		4,820
		$	8,690

See Note 15 for discussion of the plan’s fair value disclosures.

Historical and future expected returns of multiple asset classes were analyzed to develop a risk-free real rate of return and risk premiums for each asset class. The overall rate for each asset class was developed by combining a long-term inflation component, the risk-free real rate of return, and the associated risk premium. A weighted average rate was developed based on those overall rates and the target asset allocation of the plan.

The Company’s pension committee is responsible for overseeing the investment of pension plan assets. The pension committee is responsible for determining and monitoring the appropriate asset allocations and for selecting or replacing investment managers, trustees, and custodians. The pension plan’s current investment target allocations are 50% equities and 50% debt. The pension committee reviews the actual asset allocation in light of these targets periodically and rebalances investments as necessary. The pension committee also evaluates the performance of investment managers as compared to the performance of specified benchmarks and peers and monitors the investment managers to ensure adherence to their stated investment style and to the plan’s investment guidelines.

Postretirement Plan - The Company also sponsors a health care plan and life insurance plan (the “Postretirement Plan”) that provides postretirement medical benefits and life insurance to certain “grandfathered” unionized employees. The Company assumed the Postretirement Plan as part of its acquisition of PE Central on July 1, 2015. Employees hired after December 31, 2000, are not eligible to participate in the Postretirement Plan. The 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.

Information related to the Postretirement Plan as of December 31, 2017 and 2016 is presented below (dollars in thousands):

	2017			2016
Amounts at the end of the year:
Accumulated/projected benefit obligation	$	5,565		$	5,371
Fair value of plan assets		—			—
Funded status, (underfunded)/overfunded	$	(5,565	)	$	(5,371	)
Amounts recognized in the consolidated balance sheets:
Accrued liabilities	$	(240	)	$	(310	)
Other liabilities	$	(5,325	)	$	(5,061	)
Accumulated other comprehensive loss	$	1,508		$	1,573

F-36

PACIFIC ETHANOL, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Information related to the Postretirement Plan for the years ended December 31, 2017, 2016 and 2015 is presented below (dollars in thousands):

	Years Ended December 31,
	2017			2016			2015
Amounts recognized in the plan for the year:
Company contributions	$	157		$	163		$	20
Participant contributions	$	22		$	22		$	15
Benefits paid	$	(179	)	$	(184	)	$	(35	)
Components of net periodic benefit costs are as follows:
Service cost	$	84		$	48		$	32
Interest cost		198			139			65
Amortization of prior service costs		134			—			—
Net periodic benefit cost	$	416		$	187		$	97
Loss (gain) recognized in other comprehensive income	$	(65	)	$	1,728		$	(155	)
Discount rate used in computation of benefit obligations		3.80	%		3.95	%		3.67	%

The Company does not expect to recognize any amortization of net actuarial loss during the year ended December 31, 2018.

The following table summarizes the expected benefit payments for the Company’s plan for each of the next five fiscal years and in the aggregate for the five fiscal years thereafter (in thousands):

December 31:
	2018	$	240
	2019		270
	2020		300
	2021		340
	2022		330
	2023-27		2,120
		$	3,600

F-37

PACIFIC ETHANOL, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

For purposes of determining the cost and obligation for pre-Medicare postretirement medical benefits, a 7.0% annual rate of increase in the per capita cost of covered benefits (i.e., health care trend rate) was assumed for the plan in 2018, adjusting to a rate of 4.5% in 2026. Assumed health care cost trend rates have a significant effect on the amounts reported for health care plans.

10. INCOME TAXES.

The Company recorded a provision (benefit) for income taxes as follows (in thousands):

	Years Ended December 31,
	2017			2016			2015
Current provision (benefit)	$	(490	)	$	141		$	(8,011	)
Deferred provision (benefit)		169			(1,122	)		(2,023	)
Total	$	(321	)	$	(981	)	$	(10,034	)

A reconciliation of the differences between the United States statutory federal income tax rate and the effective tax rate as provided in the consolidated statements of operations is as follows:

	Years Ended December 31,
	2017			2016			2015
Statutory rate		35.0	%		35.0	%		35.0	%
State income taxes, net of federal benefit		4.0			6.4			9.2
Change in valuation allowance		(34.5	)		(298.8	)		(4.2	)
Impact of Federal tax rate change on deferreds		(28.4	)		—			—
Impact of Federal tax rate change on valuation allowance		29.4			—			—
Fair value adjustments and warrant inducements		0.4			37.2			2.0
Noncontrolling interests		(3.2	)		—			—
Domestic production gross receipts deduction		—			—			(2.9	)
Section 382 reduction to loss carryover		—			—			0.1
Stock compensation		(0.1	)		58.8			(0.8	)
Non-deductible items		(0.2	)		8.9			(0.5	)
Other		(1.6	)		(27.5	)		(3.2	)
Effective rate		0.8	%		(180.0	)%		34.7	%

F-38

PACIFIC ETHANOL, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Deferred income taxes are provided using the asset and liability method to reflect temporary differences between the financial statement carrying amounts and the tax bases of assets and liabilities using presently enacted tax rates and laws. The components of deferred income taxes included in the consolidated balance sheets were as follows (in thousands):

	December 31,
	2017			2016
Deferred tax assets:
Net operating loss carryforwards	$	40,989		$	45,709
R&D and AMT credits		1,797			2,465
Railcar contracts		1,415			3,348
Stock-based compensation		738			946
Allowance for doubtful accounts and other assets		637			856
Derivatives		267			1,228
Pension liability		2,939			2,204
Other		2,097			4,316
Total deferred tax assets		50,879			61,072
Deferred tax liabilities:
Property and equipment		(25,194	)		(45,757	)
Intangibles		(749	)		(1,091	)
Other		(521	)		(1,593	)
Total deferred tax liabilities		(26,464	)		(48,441	)
Valuation allowance		(24,639	)		(12,683	)
Net deferred tax liabilities, included in other liabilities	$	(224	)	$	(52	)

A portion of the Company’s net operating loss carryforwards will be subject to provisions of the tax law that limit the use of losses incurred by a company prior to the date certain ownership changes occur. Due to the limitation, a significant portion of these net operating loss carryforwards will expire regardless of whether the Company generates future taxable income. After reducing these net operating loss carryforwards for the amount which will expire due to this limitation, the Company had remaining federal net operating loss carryforwards of approximately $154,589,000 and state net operating loss carryforwards of approximately $148,921,000 at December 31, 2017. These net operating loss carryforwards expire as follows (in thousands):

Tax Years	Federal		State
2018–2022	$	—	$	—
2023–2027		13,038		2,945
2028–2032		22,025		65,921
2033–2036		119,526		80,055
	$	154,589	$	148,921

Certain of these net operating losses are not immediately available, but become available to be utilized in each of the years ended December 31, as follows (in thousands):

Year	Federal		State
2017	$	59,675	$	82,892
2018		6,441		5,372
2019		6,374		5,345
2020		6,308		5,318
2021		6,308		5,318
Thereafter		69,483		44,676
	$	154,589	$	148,921

F-39

PACIFIC ETHANOL, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

To the extent amounts are not utilized in any year, they may be carried forward to the next year until expiration. These amounts may change if there are future additional limitations on their utilization.

In assessing whether the deferred tax assets are realizable, a more likely than not standard is applied. If it is determined that it is more likely than not that deferred tax assets will not be realized, a valuation allowance must be established against the deferred tax assets. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which the associated temporary differences become deductible. Management considers the scheduled reversal of deferred tax liabilities, projected future taxable income and tax planning strategies in making this assessment.

A valuation allowance was established in the amount of $22,585,000, $12,683,000 and $39,838,000 at December 31, 2017, 2016 and 2015, respectively, based on the Company’s assessment of the future realizability of certain deferred tax assets. The valuation allowance on deferred tax assets is related to future deductible temporary differences and net operating loss carryforwards (exclusive of net operating losses associated with items recorded directly to equity) for which the Company has concluded it is more likely than not that these items will not be realized in the ordinary course of operations.

For the year ended December 31, 2017, the Company recorded an increase in the valuation allowance of $11,956,000. This increase was primarily the offsetting impact of a decrease in deferred tax liabilities associated with property and equipment, as a result of the finalization of the deferred tax attributes of Pacific Aurora, which was subject to a 2016 sale of a noncontrolling interest. For the year ended December 31, 2016, the Company recorded a decrease in the valuation allowance of $27,155,000, including approximately $13,500,000 related to finalizing, certain aspects of the deferred tax attributes of the 2015 PE Central acquisition, and approximately $11,500,000 related to the sale of the noncontrolling interest in Pacific Aurora, which had the impact of an increase in both the net deferred tax asset and related valuation allowance. For the year ended December 31, 2015, the Company recognized $1,500,000 in tax benefit related to adjustments to its tax asset valuation allowance from a prior year.

At December 31, 2017, the Company accrued $235,000 in tax uncertainties. There was no accrued interest or penalties relating to tax uncertainties at December 31, 2016.

The Tax Cuts and Jobs Act (“TCJA”) was enacted on December 22, 2017. The Company recognized the income tax effects of the TCJA in its 2017 financial statements in accordance with Staff Accounting Bulletin No. 118, which provides SEC staff guidance for the application of ASC Topic 740, Income Taxes, in the reporting period in which the TCJA was signed into law. As such, the Company’s financial results reflect the income tax effects of the TCJA for which the accounting under ASC Topic 740 is complete. The Company did not identify items for which the income tax effects of the TCJA have not been completed and a reasonable estimate could not be determined as of December 31, 2017.

Amounts recorded where accounting is complete principally relate to the reduction in the U.S. corporate income tax rate to 21%, which resulted in the Company reporting an income tax benefit of $321,000 to remeasure deferred taxes liabilities associated with indefinitely lived intangible assets that will reverse at the new 21% rate. This rate reduction decreased gross deferred assets by approximately $10,170,000 and valuation allowance by $10,545,000. Absent this deferred tax liability, the Company is in a net deferred tax asset position that is offset by a full valuation allowance, resulting in a net tax effect of zero.

Other significant provisions of the TCJA that are not yet effective but may impact income taxes in future years include: additional limitations on certain meals and entertainment expenses, the inclusion of commissions and performance-based compensation in determining the excessive compensation limitation, limitation on the current deductibility of net interest expense in excess of 30% of adjusted taxable income, and a limitation of net operating losses generated after fiscal 2018 to 80% of taxable income.

F-40

PACIFIC ETHANOL, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

The Company is subject to income tax in the United States federal jurisdiction and various state jurisdictions and has identified its federal tax return and tax returns in state jurisdictions below as “major” tax filings. These jurisdictions, along with the years still open to audit under the applicable statutes of limitation, are as follows:

Jurisdiction	Tax Years
Federal	2014 – 2016
Arizona	2014 – 2016
California	2013 – 2016
Colorado	2013 – 2016
Idaho	2014 – 2016
Illinois	2014 – 2016
Indiana	2014 – 2016
Iowa	2014 – 2016
Kansas	2014 – 2016
Minnesota	2014 – 2016
Missouri	2014 – 2016
Nebraska	2014 – 2016
Oklahoma	2014 – 2016
Oregon	2014 – 2016
Texas	2013 – 2016

However, because the Company had net operating losses and credits carried forward in several of the jurisdictions, including the United States federal and California jurisdictions, certain items attributable to closed tax years are still subject to adjustment by applicable taxing authorities through an adjustment to tax attributes carried forward to open years.

11. PREFERRED STOCK.

The Company has 6,734,835 undesignated shares of authorized and unissued preferred stock, which may be designated and issued in the future on the authority of the Company’s Board of Directors. As of December 31, 2017, the Company had the following designated preferred stock:

Series A Preferred Stock – The Company has authorized 1,684,375 shares of Series A Cumulative Redeemable Convertible Preferred Stock (“Series A Preferred Stock”), with none outstanding at December 31, 2017 and 2016. Shares of Series A Preferred Stock that are converted into shares of the Company’s common stock revert to undesignated shares of authorized and unissued preferred stock.

Upon any issuance, the Series A Preferred Stock would rank senior in liquidation and dividend preferences to the Company’s common stock. Holders of Series A Preferred Stock would be entitled to quarterly cumulative dividends payable in arrears in cash in an amount equal to 5% per annum of the purchase price per share of the Series A Preferred Stock. The holders of the Series A Preferred Stock would have conversion rights initially equivalent to two shares of common stock for each share of Series A Preferred Stock, subject to customary antidilution adjustments. Certain specified issuances will not result in antidilution adjustments. The shares of Series A Preferred Stock would also be subject to forced conversion upon the occurrence of a transaction that would result in an internal rate of return to the holders of the Series A Preferred Stock of 25% or more. Accrued but unpaid dividends on the Series A Preferred Stock are to be paid in cash upon any conversion of the Series A Preferred Stock.

F-41

PACIFIC ETHANOL, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

The holders of Series A Preferred Stock would have a liquidation preference over the holders of the Company’s common stock equivalent to the purchase price per share of the Series A Preferred Stock plus any accrued and unpaid dividends on the Series A Preferred Stock. A liquidation would be deemed to occur upon the happening of customary events, including transfer of all or substantially all of the Company’s capital stock or assets or a merger, consolidation, share exchange, reorganization or other transaction or series of related transactions, unless holders of 66 2/3% of the Series A Preferred Stock vote affirmatively in favor of or otherwise consent to such transaction.

Series B Preferred Stock – The Company has authorized 1,580,790 shares of Series B Cumulative Convertible Preferred Stock (“Series B Preferred Stock”), with 926,942 shares outstanding at December 31, 2017 and 2016. Shares of Series B Preferred Stock that are converted into shares of the Company’s common stock revert to undesignated shares of authorized and unissued preferred stock.

The Series B Preferred Stock ranks senior in liquidation and dividend preferences to the Company’s common stock. Holders of Series B Preferred Stock are entitled to quarterly cumulative dividends payable in arrears in cash in an amount equal to 7.00% per annum of the purchase price per share of the Series B Preferred Stock; however, subject to the provisions of the Letter Agreement described below, such dividends may, at the option of the Company, be paid in additional shares of Series B Preferred Stock based initially on the liquidation value of the Series B Preferred Stock. In addition to the quarterly cumulative dividends, holders of the Series B Preferred Stock are entitled to participate in any common stock dividends declared by the Company to its common stockholders. The holders of Series B Preferred Stock have a liquidation preference over the holders of the Company’s common stock initially equivalent to $19.50 per share of the Series B Preferred Stock plus any accrued and unpaid dividends on the Series B Preferred Stock. A liquidation will be deemed to occur upon the happening of customary events, including the transfer of all or substantially all of the capital stock or assets of the Company or a merger, consolidation, share exchange, reorganization or other transaction or series of related transaction, unless holders of 66 2/3% of the Series B Preferred Stock vote affirmatively in favor of or otherwise consent that such transaction shall not be treated as a liquidation. The Company believes that such liquidation events are within its control and therefore has classified the Series B Preferred Stock in stockholders’ equity.

As of December 31, 2017, the Series B Preferred Stock was convertible into 634,641 shares of the Company’s common stock. The conversion ratio is subject to customary antidilution adjustments. In addition, antidilution adjustments are to occur in the event that the Company issues equity securities, including derivative securities convertible into equity securities (on an as-converted or as-exercised basis), at a price less than the conversion price then in effect. The shares of Series B Preferred Stock are also subject to forced conversion upon the occurrence of a transaction that would result in an internal rate of return to the holders of the Series B Preferred Stock of 25% or more. The forced conversion is to be based upon the conversion ratio as last adjusted. Accrued but unpaid dividends on the Series B Preferred Stock are to be paid in cash upon any conversion of the Series B Preferred Stock.

F-42

PACIFIC ETHANOL, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

The holders of Series B Preferred Stock vote together as a single class with the holders of the Company’s common stock on all actions to be taken by the Company’s stockholders. Each share of Series B Preferred Stock entitles the holder to approximately 0.03 votes per share on all matters to be voted on by the stockholders of the Company. Notwithstanding the foregoing, the holders of Series B Preferred Stock are afforded numerous customary protective provisions with respect to certain actions that may only be approved by holders of a majority of the shares of Series B Preferred Stock.

In 2008, the Company entered into Letter Agreements with Lyles United LLC (“Lyles United”) and other purchasers under which the Company expressly waived its rights under the Certificate of Designations relating to the Series B Preferred Stock to make dividend payments in additional shares of Series B Preferred Stock in lieu of cash dividend payments without the prior written consent of Lyles United and the other purchasers.

Registration Rights Agreement – In connection with the sale of its Series B Preferred Stock, the Company entered into a registration rights agreement with Lyles United. The registration rights agreement is to be effective until the holders of the Series B Preferred Stock, and their affiliates, as a group, own less than 10% for each of the series issued, including common stock into which such Series B Preferred Stock has been converted. The registration rights agreement provides that holders of a majority of the Series B Preferred Stock, including common stock into which such Series B Preferred Stock has been converted, may demand and cause the Company to register on their behalf the shares of common stock issued, issuable or that may be issuable upon conversion of the Preferred Stock and as payment of dividends thereon, and upon exercise of the related warrants (collectively, the “Registrable Securities”). The Company is required to keep such registration statement effective until such time as all of the Registrable Securities are sold or until such holders may avail themselves of Rule 144 for sales of Registrable Securities without registration under the Securities Act of 1933, as amended. The holders are entitled to two demand registrations on Form S-1 and unlimited demand registrations on Form S-3; provided, however, that the Company is not obligated to effect more than one demand registration on Form S-3 in any calendar year. In addition to the demand registration rights afforded the holders under the registration rights agreement, the holders are entitled to unlimited “piggyback” registration rights. These rights entitle the holders who so elect to be included in registration statements to be filed by the Company with respect to other registrations of equity securities. The Company is responsible for all costs of registration, plus reasonable fees of one legal counsel for the holders, which fees are not to exceed $25,000 per registration. The registration rights agreement includes customary representations and warranties on the part of both the Company and the holders and other customary terms and conditions.

The Company accrued and paid in cash preferred stock dividends of $1,265,000, $1,269,000 and $1,265,000 for the years ended December 31, 2017, 2016 and 2015, respectively.

F-43

PACIFIC ETHANOL, INC. 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

12. COMMON STOCK AND WARRANTS.

The following table summarizes warrant activity for the years ended December 31, 2017, 2016 and 2015 (number of shares in thousands):

	Number of Shares			Price per Share	Weighted Average Exercise Price
Balance at December 31, 2014		856		$6.09 – $735.00	$	36.55
Warrants exercised		(42	)	$8.85	$	8.85
Warrants expired		(432	)	$8.85	$	8.85
Balance at December 31, 2015		382		$6.09 – $735.00	$	70.87
Warrants exercised		(138	)	$8.43	$	8.43
Balance at December 31, 2016		244		$6.09 – $735.00	$	106.72
Warrants exercised		(191	)	$6.09	$	6.09
Warrants expired		(49	)	$6.09 – $735.00	$	444.00
Balance at December 31, 2017		4		$735.00	$	735.00

July 2012 Public Offering – On July 3, 2012, in connection with a public offering, the Company issued warrants to purchase an aggregate of 1,867,000 shares of the Company’s common stock. The warrants were issued at an initial exercise price of $9.45 per share, which was subject to certain “weighted-average” anti-dilution adjustments. As a result of anti-dilution adjustments, the exercise price was reduced to $6.09 per share. The balance of these warrants expired unexercised in 2017.

Accounting for Warrants – The Company determined that certain warrants issued in 2011 and 2012 did not meet the conditions for classification in stockholders’ equity and, as such, the Company recorded them as a liability at fair value. The Company revalued them at each reporting period. Accordingly, the Company recorded fair value adjustments quarterly, with total fair value adjustments of $473,000, $(557,000) and $1,641,000 of income (expense) for the years ended December 31, 2017, 2016 and 2015, respectively, which was largely attributed to adjustments to their exercise prices, term shortening and changes in the market value of the Company’s common stock. See Note 15 for the Company’s fair value assumptions. As of December 31, 2017, there were no warrants outstanding for which the Company accounts using fair value methodologies. Accordingly, no fair value adjustments will be made in the future periods related to currently outstanding warrants.

Nonvoting Common Stock – In connection with the Company’s PE Central acquisition, the Company issued nonvoting common shares exercisable at the holders’ election. During the year ended December 31, 2017, 3,539,236 shares of nonvoting common stock were exchanged for an equal number of shares of the Company’s common stock upon the holders’ request.

13. STOCK-BASED COMPENSATION.

The Company has two equity incentive compensation plans: a 2006 Stock Incentive Plan and a 2016 Stock Incentive Plan.

2006 Stock Incentive Plan – The 2006 Stock Incentive Plan authorized the issuance of incentive stock options (“ISOs”) and non-qualified stock options (“NQOs”), restricted stock, restricted stock units, stock appreciation rights, direct stock issuances and other stock-based awards to the Company’s officers, directors or key employees or to consultants that do business with the Company for up to an aggregate of 1,715,000 shares of common stock. In June 2016, this plan was terminated, except to the extent of issued and outstanding unvested stock awards and options.

2016 Stock Incentive Plan – On June 16, 2016, the Company’s shareholders approved the 2016 Stock Incentive Plan, which authorizes the issuance of ISOs, NQOs, restricted stock, restricted stock units, stock appreciation rights, direct stock issuances and other stock-based awards to the Company’s officers, directors or key employees or to consultants that do business with the Company for up to an aggregate of 1,150,000 shares of common stock.

F-44

PACIFIC ETHANOL, INC. 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Stock Options – Summaries of the status of Company’s stock option plans as of December 31, 2017 and 2016 and of changes in options outstanding under the Company’s plans during those years are as follows (number of shares in thousands):

	Years Ended December 31,
	2017					2016
	Number of Shares			Weighted Average Exercise Price		Number of Shares		Weighted Average Exercise Price
Outstanding at beginning of year		240		$	4.18		240	$	4.18
Exercised		(10	)		3.74		—		—
Outstanding at end of year		230		$	4.18		240	$	4.18
Options exercisable at end of year		230		$	4.18		240	$	4.18

Stock options outstanding as of December 31, 2017 were as follows (number of shares in thousands): 

		Options Outstanding				Options Exercisable
	Range of Exercise Prices	Number Outstanding	Weighted Average Remaining Contractual Life (yrs.)		Weighted Average  Exercise  Price	Number Exercisable		Weighted  Average  Exercise Price
$	3.74	219	5.47	$	3.74	219	$	3.74
$	12.90	11	3.59	$	12.90	11	$	12.90

The options outstanding at December 31, 2017 and 2016 had intrinsic values of $84,000 and $1,319,000, respectively. The intrinsic value of options exercised in 2017 was approximately $30,000.

F-45

PACIFIC ETHANOL, INC. 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Restricted Stock – The Company granted to certain employees and directors shares of restricted stock under its 2006 and 2016 Stock Incentive Plans. A summary of unvested restricted stock activity is as follows (shares in thousands):

	Number of Shares			Weighted Average Grant Date  Fair Value Per Share
Unvested at December 31, 2014		390		$	8.71
Issued		307		$	10.16
Vested		(220	)	$	7.94
Canceled		(14	)	$	10.08
Unvested at December 31, 2015		463		$	10.00
Issued		742		$	5.24
Vested		(250	)	$	9.01
Canceled		(25	)	$	6.24
Unvested at December 31, 2016		930		$	6.57
Issued		664		$	6.65
Vested		(480	)	$	7.30
Canceled		(37	)	$	6.08
Unvested at December 31, 2017		1,077		$	6.31

The fair value of the common stock at vesting aggregated $3,210,000, $1,142,000 and $2,603,000 for the years ended December 31, 2017, 2016 and 2015, respectively. Stock-based compensation expense related to employee and non-employee restricted stock and option grants recognized in selling, general and administrative expenses, were as follows (in thousands):

	Years Ended December 31,
	2017		2016		2015
Employees	$	3,303	$	2,173	$	1,694
Non-employees		525		443		325
Total stock-based compensation expense	$	3,828	$	2,616	$	2,019

Employee grants typically have a three year vesting schedule, while the non-employee grants have a one year vesting schedule. At December 31, 2017, the total compensation expense related to unvested awards which had not been recognized was $4,122,000 and the associated weighted-average period over which the compensation expense attributable to those unvested awards will be recognized was approximately 1.54 years.

F-46

PACIFIC ETHANOL, INC. 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

14. COMMITMENTS AND CONTINGENCIES.

Commitments – The following is a description of significant commitments at December 31, 2017:

Leases – Future minimum lease payments required by non-cancelable leases in effect at December 31, 2017 were as follows (in thousands):

Years Ended December 31,	Capital Leases			Operating Leases
2018	$	613		$	11,841
2019		45			9,236
2020		45			7,042
2021		34			4,074
2022		—			3,894
Thereafter		—			5,530
Total minimum payments		737		$	41,617
Amount representing interest		(22	)
Obligations under capital leases		715
Obligations due within one year		(592	)
Long-term obligations under capital leases	$	123

Total rent expense during the years ended December 31, 2017, 2016 and 2015 was $16,572,000, $16,253,000 and $10,476,000, respectively.

Sales Commitments – The Company had open ethanol indexed-price contracts for 310,289,000 gallons of ethanol as of December 31, 2017 and open fixed-price ethanol sales contracts totaling $90,389,000 as of December 31, 2017. The Company had open fixed-price co-product sales contracts totaling $35,600,000 as of December 31, 2017. These sales contracts are scheduled to be completed throughout 2018.

Purchase Commitments – At December 31, 2017, the Company had indexed-price purchase contracts to purchase 16,149,000 gallons of ethanol and fixed-price purchase contracts to purchase $8,932,000 of ethanol from its suppliers. The Company had fixed-price purchase contracts to purchase $21,134,000 of corn from its suppliers. These purchase commitments are scheduled to be satisfied throughout 2018. 

Property Tax Assessment – In September 2016, the Company signed an agreement to finance and construct a 5 megawatt solar project at its Madera facility. The amount financed is for up to $10.0 million, to be amortized over twenty years as part of the facility’s property tax assessments. As of December 31, 2017, the Company had incurred $7.7 million in project costs, which is recorded in construction in progress and in other liabilities in the accompanying consolidated balance sheets. The Company expects to pay an additional $0.9 million per year in connection with its property tax payments, which includes an interest component based upon a 5.6% interest rate on the outstanding balance of the assessment.

Other Commitments – At December 31, 2017, the Company had firm commitments for various capital and process improvement projects at the Company’s plants of approximately $4,100,000, which are expected to be completed in 2018.

F-47

PACIFIC ETHANOL, INC. 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Contingencies – The following is a description of significant contingencies at December 31, 2017:

Litigation – 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 financial impact on the Company’s operating results.

The Company assumed certain legal matters which were ongoing at July 1, 2015, the date of the Company’s acquisition of 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 PE Central 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 as a reduction to selling, general and administrative expenses in the consolidated statements of operations for the year ended December 31, 2017.

Pacific Ethanol, Inc., through a subsidiary acquired in its acquisition of PE Central, became involved in a pending lawsuit with Western Sugar Cooperative (“Western Sugar”) that pre-dated the acquisition. On February 27, 2015, Western Sugar filed a complaint in the United States District Court for the District of Colorado (Case No. 1:15-cv-00415) naming PE Central’s subsidiary as defendant. The PE Central subsidiary purchased surplus sugar through a United States Department of Agriculture program. Western Sugar was one of the entities that warehoused this sugar for the PE Central subsidiary. The suit alleged that the PE Central subsidiary breached its contract with Western Sugar by failing to pay certain penalty rates for the storage of its sugar or alternatively failing to pay a premium rate for storage. Western Sugar alleged that the penalty rates applied because the PE Central subsidiary failed to take timely delivery or otherwise cause timely shipment of the sugar. Western Sugar claimed “expectation damages” in the amount of approximately $8.6 million. On December 29, 2016, Western Sugar and the PE Central subsidiary entered into a settlement pursuant to which the PE Central subsidiary paid $1.7 million and Western Sugar filed a Stipulation of Dismissal with prejudice. As a result, the Company reduced its litigation reserve of $2.8 million and recognized the recovery of $1.1 million as a reduction to selling, general and administrative expenses for the year ended December 31, 2016.

On May 24, 2013, GS CleanTech Corporation (“GS CleanTech”), filed a suit in the United States District Court for the Eastern District of California, Sacramento Division (Case No.: 2:13-CV-01042-JAM-AC), naming Pacific Ethanol, Inc. as a defendant. On August 29, 2013, the case was transferred to the United States District Court for the Southern District of Indiana and made part of the pre-existing multi-district litigation involving GS CleanTech and multiple defendants. The suit alleged infringement of a patent assigned to GS CleanTech by virtue of certain corn oil separation technology in use at one or more of the ethanol production facilities in which the Company has an interest, including Pacific Ethanol Stockton LLC (“PE Stockton”), located in Stockton, California. The complaint sought preliminary and permanent injunctions against the Company, prohibiting future infringement on the patent owned by GS CleanTech and damages in an unspecified amount adequate to compensate GS CleanTech for the alleged patent infringement, but in any event no less than a reasonable royalty for the use made of the inventions of the patent, plus attorneys’ fees. The Company answered the complaint, counterclaimed that the patent claims at issue, as well as the claims in several related patents, are invalid and unenforceable and that the Company is not infringing. Pacific Ethanol, Inc. does not itself use any corn oil separation technology and may seek a dismissal on those grounds.

F-48

PACIFIC ETHANOL, INC. 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

On March 17 and March 18, 2014, GS CleanTech filed suit naming as defendants two Company subsidiaries: PE Stockton and Pacific Ethanol Magic Valley, LLC (“PE Magic Valley”). The claims were similar to those filed against Pacific Ethanol, Inc. in May 2013. These two cases were transferred to the multi-district litigation division in United States District Court for the Southern District of Indiana, where the case against Pacific Ethanol, Inc. was pending. Although PE Stockton and PE Magic Valley do separate and market corn oil, Pacific Ethanol, Inc., PE Stockton and PE Magic Valley strongly disagree that either of the subsidiaries use corn oil separation technology that infringes the patent owned by GS CleanTech. In a January 16, 2015 decision, the District Court for the Southern District of Indiana ruled in favor of a stipulated motion for partial summary judgment for Pacific Ethanol, Inc., PE Stockton and PE Magic Valley finding that all of the GS CleanTech patents in the suit were invalid and, therefore, not infringed.

A trial in the District Court for the Southern District of Indiana was conducted in October 2015 on the inequitable conduct issue as well as whether GS CleanTech’s behavior during prosecution of the patents rendered this an “exceptional case” which would allow the District Court to award the Defendants reimbursement of their attorneys’ fees expended for defense of the case.

On September 15, 2016, the District Court issued an Order finding that GS CleanTech, the inventors and GS CleanTech’s counsel committed inequitable conduct in the prosecution of the GS CleanTech patents before the United States Patent and Trademark Office. As a result, the District Court issued a Final Judgment on September 15, 2016 dismissing with prejudice all of GS CleanTech’s cases against the Defendants, including Pacific Ethanol, Inc., PE Stockton and PE Magic Valley. The District Court’s ruling of inequitable conduct results in the unenforceability of the GS CleanTech patents against third parties, and also enables the Defendants to pursue reimbursement of their costs and attorneys’ fees from GS CleanTech and its counsel. GS CleanTech subsequently appealed the District Court’s finding that all of the GS CleanTech patents were invalid and its finding that the inventors and GS CleanTech’s counsel committed inequitable conduct. The Court of Appeals for the Federal Circuit ordered the appeals stayed until June 15, 2018, pending rulings on certain procedural motions.

The Company has evaluated the above cases as well as other pending cases. The Company currently has not recorded a litigation contingency liability with respect to these cases.

15.  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

F-49

PACIFIC ETHANOL, INC. 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

● 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.

Pooled separate accounts – Pooled separate accounts invest primarily in domestic and international stocks, commercial paper or single mutual funds. The net asset value is used as a practical expedient to determine fair value for these accounts. Each pooled separate account provides for redemptions by the Retirement Plan at reported net asset values per share, with little to no advance notice requirement, therefore these funds are classified within Level 2 of the valuation hierarchy.

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 from 2011 through 2012 at fair value and designated them as Level 3 on their issuance dates. All of such warrants were retired as of December 31, 2017.

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 December 31, 2017 (in thousands):

F-50

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

											Benefit Plan
	Fair										Percentage
	Value			Level 1			Level 2		Level 3		Allocation
Assets:
Derivative financial instruments(1)	$	998		$	998		$	—	$	—
Defined benefit plan assets(2) (pooled separate accounts):
Large U.S. Equity(3)		3,748			—			3,748		—		27	%
Small/Mid U.S. Equity(4)		2,018			—			2,018		—		14	%
International Equity(5)		2,528			—			2,528		—		18	%
Fixed Income(6)		5,664			—			5,664		—		41	%
	$	14,956		$	998		$	13,958	$	—
Liabilities:
Derivative financial instruments(7)	$	(2,307	)	$	(2,307	)	$	—	$	—

F-51

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

The following table summarizes recurring fair value measurements by level at December 31, 2016 (in thousands):

												Benefit Plan
	Fair											Percentage
	Value			Level 1			Level 2		Level 3			Allocation
Assets:
Derivative financial instruments(1)	$	978		$	978		$	—	$	—
Defined benefit plan assets(2) (pooled separate accounts):
Large U.S. Equity(3)		3,134			—			3,134		—			25	%
Small/Mid U.S. Equity(4)		1,802			—			1,802		—			15	%
International Equity(5)		2,006			—			2,006		—			16	%
Fixed Income(6)		5,481			—			5,481		—			44	%
	$	13,401		$	978		$	12,423	$	—
Liabilities:
Warrants(8)	$	(651	)	$	—		$	—	$	(651	)
Derivative financial instruments(7)		(4,115	)		(4,115	)		—		—
	$	(4,766	)	$	(4,115	)	$	—	$	(651	)

(1) Included in derivative assets in the consolidated balance sheets.

(2) See Note 9 for accounting discussion.

(3) This category includes investments in funds comprised of equity securities of large U.S. companies. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(4) This category includes investments in funds comprised of equity securities of small- and medium-sized U.S. companies. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(5) This category includes investments in funds comprised of equity securities of foreign companies including emerging markets. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(6) This category includes investments in funds comprised of U.S. and foreign investment-grade fixed income securities, high-yield fixed income securities that are rated below investment-grade, U.S. treasury securities, mortgage-backed securities, and other asset-backed securities. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(7) Included in derivative liabilities in the consolidated balance sheets.

(8) Included in warrant liabilities at fair value in the consolidated balance sheets.

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

F-52

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

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

	Warrants
Balance, December 31, 2014	$	1,986
Exercises of warrants		(72	)
Expiration of warrants		(527	)
Adjustments to fair value for the period		(1,114	)
Balance, December 31, 2015	$	273
Exercises of warrants		(179	)
Adjustments to fair value for the period		557
Balance, December 31, 2016	$	651
Exercises of warrants		(178	)
Adjustments to fair value for the period		(473	)
Balance, December 31, 2017	$	—

16. PARENT COMPANY FINANCIALS.

Restricted Net Assets – At December 31, 2017, the Company had approximately $302,900,000 of net assets at its subsidiaries that were not available to be transferred to Pacific Ethanol in the form of dividends, distributions, loans or advances due to restrictions contained in the credit facilities of these subsidiaries.

Parent company financial statements for the periods covered in this report are set forth below.

	December 31,
	2017			2016
ASSETS
Current Assets:
Cash and cash equivalents	$	5,314		$	11,060
Receivables from subsidiaries		3,138			7,203
Other current assets		1,631			6,442
Total current assets		10,083			24,705
Property and equipment, net		1,071			1,433
Other Assets:
Investments in subsidiaries		359,680			363,401
Pacific Ethanol West plant receivable		58,766			58,766
Other assets		1,565			1,110
Total other assets		420,011			423,277
Total Assets	$	431,165		$	449,415
Current Liabilities:
Accounts payable and accrued liabilities	$	2,218		$	1,758
Payable to subsidiaries		625			1,568
Accrued PE Op Co. purchase		3,828			3,828
Other current liabilities		245			184
Total current liabilities		6,916			7,338
Long-term debt, net		67,530			53,360
Warrant liabilities at fair value		—			651
Deferred tax liabilities		224			52
Other liabilities		56			124
Total Liabilities		74,726			61,525
Stockholders’ Equity:
Preferred stock		1			1
Common and non-voting common stock		44			44
Additional paid-in capital		927,090			922,698
Accumulated other comprehensive loss		(2,234	)		(2,620	)
Accumulated deficit		(568,462	)		(532,233	)
Total Pacific Ethanol, Inc. stockholders’ equity		356,439			387,890
Total Liabilities and Stockholders’ Equity	$	431,165		$	449,415

F-53

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

	Years Ended December 31,
	2017			2016			2015
Management fees from subsidiaries	$	11,904		$	12,968		$	9,857
Selling, general and administrative expenses		18,185			14,491			14,336
Asset impairment		—			—			1,970
Loss from operations		(6,281	)		(1,523	)		(6,449	)
Fair value adjustments		473			(557	)		1,641
Interest income		4,793			5,964			5,739
Interest expense		(5,829	)		(240	)		(27	)
Other income (expense), net		(95	)		1,931			—
Income (loss) before provision for income taxes		(6,939	)		5,575			904
Provision (benefit) for income taxes		(321	)		(981	)		(10,034	)
Income (loss) before equity in earnings of subsidiaries		(6,618	)		6,556			10,938
Equity in losses of subsidiaries		(28,346	)		(5,137	)		(29,724	)
Consolidated net income (loss)	$	(34,964	)	$	1,419		$	(18,786	)

F-54

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

	For the Years Ended December 31,
	2017			2016			2015
Operating Activities:
Net income (loss)	$	(34,964	)	$	1,419		$	(18,786	)
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Equity in losses of subsidiaries		28,346			5,137			29,724
Dividends from subsidiaries		3,500			—			—
Depreciation and amortization		830			727			390
Fair value adjustments		(473	)		557			(1,641	)
Asset impairment		—			—			1,970
Deferred income taxes		169			(1,122	)		(14,260	)
Amortization of debt discounts		636			10			—
Changes in operating assets and liabilities:
Accounts receivables		4,065			7,302			(5,958	)
Other assets		4,356			4,647			(4,139	)
Accounts payable and accrued expenses		3,859			(3,741	)		604
Accounts payable with subsidiaries		(943	)		(9,385	)		11,179
Net cash provided by (used in) operating activities	$	9,381		$	5,551		$	(917	)
Investing Activities:
Additions to property and equipment	$	(468	)	$	(465	)	$	(1,483	)
Investments in subsidiaries		(28,126	)		(50,886	)		—
Purchase of PE OP Co. debt		—			(17,003	)		—
Net cash used in investing activities	$	(28,594	)	$	(68,354	)	$	(1,483	)
Financing Activities:
Proceeds from issuances of senior notes	$	13,530		$	53,350		$	—
Proceeds from warrant stock option exercises		1,202			1,164			368
Preferred stock dividend payments		(1,265	)		(1,269	)		(1,265	)
Net cash provided by (used in) financing activities	$	13,467		$	53,245		$	(897	)
Net decrease in cash and cash equivalents		(5,746	)		(9,558	)		(3,297	)
Cash and cash equivalents at beginning of period		11,060			20,618			23,915
Cash and cash equivalents at end of period	$	5,314		$	11,060		$	20,618

F-55

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

17. QUARTERLY FINANCIAL DATA (UNAUDITED).

The Company’s quarterly results of operations for the years ended December 31, 2017 and 2016 are as follows (in thousands). Certain of these calculations have been revised from the calculations previously reported to reflect the participating securities.

	First Quarter			Second Quarter			Third Quarter			Fourth Quarter
December 31, 2017:
Net sales	$	386,340		$	405,202		$	445,442		$	395,271
Gross profit (loss)	$	(5,773	)	$	1,653		$	12,065		$	(2,014	)
Income (loss) from operations	$	(11,223	)	$	(7,109	)	$	3,345		$	(10,598	)
Net loss attributed to Pacific Ethanol, Inc.	$	(12,636	)	$	(8,841	)	$	(202	)	$	(13,285	)
Preferred stock dividends	$	(312	)	$	(315	)	$	(319	)	$	(319	)
Net loss available to common stockholders	$	(12,948	)	$	(9,156	)	$	(521	)	$	(13,604	)
Basic and diluted loss per common share	$	(0.31	)	$	(0.22	)	$	(0.01	)	$	(0.32	)
	First Quarter			Second Quarter			Third Quarter			Fourth Quarter
December 31, 2016:
Net sales	$	342,373		$	422,860		$	417,806		$	441,719
Gross profit	$	1,668		$	18,355		$	7,021		$	27,314
Income (loss) from operations	$	(7,248	)	$	11,556		$	393		$	18,808
Net income (loss) attributed to Pacific Ethanol, Inc.	$	(13,226	)	$	5,086		$	(3,518	)	$	13,077
Preferred stock dividends	$	(315	)	$	(315	)	$	(319	)	$	(320	)
Income allocated to participating securities	$	—		$	(71	)	$	—		$	(189	)
Net income (loss) available to common stockholders	$	(13,541	)	$	4,700		$	(3,837	)	$	12,569
Basic and diluted income (loss) per common share	$	(0.32	)	$	0.11		$	(0.09	)	$	0.30

F-56

INDEX TO EXHIBITS

		Where Located
Exhibit Number	Description*	Form	File Number	Exhibit Number	Filing Date	Filed Herewith
2.1	Agreement and Plan of Merger dated as of December 30, 2014 among Pacific Ethanol, Inc., AVR Merger Sub, Inc. and Aventine Renewable Energy Holdings, Inc.	8-K	000-21467	2.1	12/31/2014
2.2	Amendment No. 1 to Agreement and Plan of Merger dated as of March 31, 2015 among Pacific Ethanol, Inc., AVR Merger Sub, Inc. and Aventine Renewable Energy Holdings, Inc.	8-K	000-21467	2.1	04/02/2015
2.3	Agreement and Plan of Merger dated June 26, 2017 among Pacific Ethanol Central, LLC, ICP Merger Sub, LLC, Illinois Corn Processing, LLC, Illinois Corn Processing Holdings Inc. and MGPI Processing, Inc.	8-K	000-21467	2.1	06/27/2017
3.1	Certificate of Incorporation	10-Q	000-21467	3.1	11/06/2015
3.2	Certificate of Designations, Powers, Preferences and Rights of the Series A Cumulative Redeemable Convertible Preferred Stock	10-Q	000-21467	3.2	11/06/2015
3.3	Certificate of Designations, Powers, Preferences and Rights of the Series B Cumulative Convertible Preferred Stock	10-Q	000-21467	3.3	11/06/2015
3.4	Certificate of Amendment to Certificate of Incorporation dated June 3, 2010	10-Q	000-21467	3.4	11/06/2015
3.5	Certificate of Amendment to Certificate of Incorporation effective June 8, 2011	10-Q	000-21467	3.5	11/06/2015
3.6	Certificate of Amendment to Certificate of Incorporation effective May 14, 2013	10-Q	000-21467	3.6	11/06/2015
3.7	Certificate of Amendment to Certificate of Incorporation effective July 1, 2015	10-Q	000-21467	3.7	11/06/2015
3.8	Amended and Restated Bylaws	10-Q	000-21467	3.1	11/12/2014
10.1	2006 Stock Incentive Plan, as amended#	S-8	333-196876	4.1	06/18/2014
10.2	Form of Employee Restricted Stock Agreement under 2006 Stock Incentive Plan#	8-K	000-21467	10.2	10/10/2006
10.3	Form of Non-Employee Director Restricted Stock Agreement under 2006 Stock Incentive Plan#	8-K	000-21467	10.3	10/10/2006
10.4	2016 Stock Incentive Plan#	S-8	333-212070	4.1	06/16/2016

INDEX TO EXHIBITS

		Where Located
Exhibit Number	Description*	Form	File Number	Exhibit Number	Filing Date	Filed Herewith
10.5	Form of Employee Restricted Stock Agreement under 2016 Stock Incentive Plan#					X
10.6	Form of Non-Employee Director Restricted Stock Agreement under 2016 Stock Incentive Plan#	10-K	000-21467	10.6	03/15/2017
10.7	Amended and Restated Executive Employment Agreement dated November 7, 2016 between the Registrant and Neil M. Koehler#	10-K	000-21467	10.7	03/15/2017
10.8	Amended and Restated Executive Employment Agreement dated November 7, 2016 between the Registrant and Christopher W. Wright#	10-K	000-21467	10.8	03/15/2017
10.9	Amended and Restated Executive Employment Agreement dated November 7, 2016 between the Registrant and Bryon T. McGregor#	10-K	000-21467	10.9	03/15/2017
10.10	Amended and Restated Executive Employment Agreement dated November 7, 2016 between the Registrant and Michael D. Kandris#	10-K	000-21467	10.10	03/15/2017
10.11	Amended and Restated Executive Employment Agreement dated November 7, 2016 between the Registrant and Paul P. Kohler#	10-K	000-21467	10.11	03/15/2017
10.12	Amended and Restated Executive Employment Agreement dated November 7, 2016 between the Registrant and James R. Sneed#	10-K	000-21467	10.12	03/15/2017
10.13	Pacific Ethanol, Inc. 2016 Short-Term Incentive Plan Description#	10-K	000-21467	10.13	03/15/2017
10.14	Pacific Ethanol, Inc. 2017 Short-Term Incentive Plan Description#	10-Q	000-21467	10.1	05/10/2017
10.15	Form of Indemnity Agreement between the Registrant and each of its Executive Officers and Directors#	10-K	000-21467	10.46	03/31/2010
10.16	Registration Rights Agreement dated March 27, 2008 between the Registrant and Lyles United, LLC	8-K	000-21467	10.4	03/27/2008
10.17	Letter Agreement dated March 27, 2008 between the Registrant and Lyles United, LLC	8-K	000-21467	10.5	03/27/2008

INDEX TO EXHIBITS

		Where Located
Exhibit Number	Description*	Form	File Number	Exhibit Number	Filing Date	Filed Herewith
10.18	Letter Agreement dated May 22, 2008 among the Registrant, Neil M. Koehler, Bill Jones, Paul P. Koehler and Thomas D. Koehler#	8-K	000-21467	10.3	05/23/2008
10.19	Form of Warrant dated May 23, 2008 issued by the Registrant to each of Neil M. Koehler, Bill Jones, Paul P. Koehler and Thomas D. Koehler#	8-K	000-21467	10.2	05/23/2008
10.20	Contribution Agreement dated December 12, 2016 among Pacific Ethanol Central, LLC, Aurora Cooperative Elevator Company and Pacific Aurora, LLC	8-K	000-21467	10.1	12/12/2016
10.21	Note Purchase Agreement dated December 12, 2016 among Pacific Ethanol, Inc. and the investors listed on the schedule of investors attached thereto	8-K	000-21467	10.2	12/12/2016
10.22	Form of Senior Secured Note for an aggregate principal amount of $55 million issued on December 15, 2016 pursuant to the Note Purchase Agreement dated December 12, 2016 among Pacific Ethanol, Inc. and the investors party thereto	8-K	000-21467	10.3	12/20/2016
10.23	Security Agreement dated December 15, 2016 among Pacific Ethanol, Inc., Cortland Capital Market Services LLC and the holders of Pacific Ethanol, Inc.’s Senior Secured Notes	8-K	000-21467	10.4	12/20/2016
10.24	Note Purchase Agreement dated June 26, 2017 among Pacific Ethanol, Inc. and the investors listed on the schedule of investors attached thereto	8-K	000-21467	10.1	06/27/2017
10.25	Consent of Holders and Amendment of Senior Secured Notes dated June 26, 2017 among Pacific Ethanol, Inc. and the holders identified therein	8-K	000-21467	10.2	06/27/2017
10.26	Form of Senior Secured Note for an aggregate principal amount of $13,948,078 issued on June 30, 2017 pursuant to the Note Purchase Agreement dated June 26, 2017 among Pacific Ethanol, Inc. and the investors party thereto	8-K	000-21467	10.3	07/05/2017

INDEX TO EXHIBITS

		Where Located
Exhibit Number	Description*	Form	File Number	Exhibit Number	Filing Date	Filed Herewith
10.27	First Amendment to Security Agreement dated June 30, 2017 among Pacific Ethanol, Inc., Cortland Capital Market Services LLC and the holders of Pacific Ethanol, Inc.’s Senior Secured Notes	8-K	000-21467	10.5	07/05/2017
10.28	Secured Promissory Note dated July 3, 2017 by Illinois Corn Processing, LLC in favor of Illinois Corn Processing Holdings Inc.	8-K	000-21467	10.6	07/05/2017
10.29	Secured Promissory Note dated July 3, 2017 by Illinois Corn Processing, LLC in favor of MGPI Processing, Inc.	8-K	000-21467	10.7	07/05/2017
10.30	Credit Agreement dated December 15, 2016 among Pacific Ethanol Pekin, Inc., 1st Farm Credit Services, PCA and CoBank, ACB	8-K	000-21467	10.5	12/20/2016
10.31	Amendment No. 1 to Credit Agreement dated March 1, 2017 among Pacific Ethanol Pekin, LLC, 1st Farm Credit Services, PCA and CoBank, ACB					X
10.32	Amendment No. 2 to Credit Agreement dated August 7, 2017 among Pacific Ethanol Pekin, LLC, 1st Farm Credit Services, PCA and CoBank, ACB	8-K	000-21467	10.1	08/11/2017
10.33	Security Agreement dated December 15, 2016 between Pacific Ethanol Pekin, Inc. and CoBank, ACB	8-K	000-21467	10.6	12/20/2016
10.34	Credit Agreement dated December 15, 2016 among Pacific Aurora, LLC, Pacific Ethanol Aurora West, LLC, Pacific Ethanol Aurora East, LLC and CoBank, ACB	8-K	000-21467	10.7	12/20/2016
10.35	Security Agreement dated December 15, 2016 among Pacific Aurora, LLC, Pacific Ethanol Aurora West, LLC, Pacific Ethanol Aurora East, LLC and CoBank, ACB	8-K	000-21467	10.8	12/20/2016
10.36	Working Capital Maintenance Agreement dated December 15, 2016 between Pacific Ethanol, Inc. and CoBank, ACB	8-K	000-21467	10.9	12/20/2016

INDEX TO EXHIBITS

		Where Located
Exhibit Number	Description*	Form	File Number	Exhibit Number	Filing Date	Filed Herewith
10.37	Second Amended and Restated Credit Agreement dated August 2, 2017 among Kinergy Marketing LLC, Pacific Ag. Products, LLC, Wells Fargo Bank, National Association, and the parties thereto from time to time as lenders	8-K	000-21467	10.1	08/08/2017
10.38	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	8-K	000-21467	10.2	08/08/2017
10.39	Credit Agreement dated September 15, 2017 between Illinois Corn Processing, LLC, Compeer Financial, PCA and CoBank, ACB	8-K	000-21467	10.1	09/21/2017
10.40	Term Note dated September 15, 2017 by Illinois Corn Processing, LLC in favor of Compeer Financial, PCA	8-K	000-21467	10.2	09/21/2017
10.41	Revolving Term Note dated September 15, 2017 by Illinois Corn Processing, LLC in favor of Compeer Financial, PCA	8-K	000-21467	10.3	09/21/2017
10.42	Illinois Future Advance Real Estate Mortgage dated September 15, 2017 by Illinois Corn Processing, LLC in favor of CoBank, ACB	8-K	000-21467	10.4	09/21/2017
10.43	Security Agreement dated September 15, 2017 by Illinois Corn Processing, LLC in favor of CoBank, ACB	8-K	000-21467	10.5	09/21/2017
21.1	Subsidiaries of the Registrant					X
23.1	Consent of Independent Registered Public Accounting Firm					X
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					X
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					X

INDEX TO EXHIBITS

		Where Located
Exhibit Number	Description*	Form	File Number	Exhibit Number	Filing Date	Filed Herewith
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					X
101.INS	XBRL Instance Document					X
101.SCH	XBRL Taxonomy Extension Schema					X
101.CAL	XBRL Taxonomy Extension Calculation Linkbase					X
101.DEF	XBRL Taxonomy Extension Definition Linkbase					X
101.LAB	XBRL Taxonomy Extension Label Linkbase					X
101.PRE	XBRL Taxonomy Extension Presentation Linkbase					X

(#) A contract, compensatory plan or arrangement to which a director or executive officer is a party or in which one or more directors or executive officers are eligible to participate.

(*)    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.

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized on this 15^th day of March, 2018.

PACIFIC ETHANOL, INC.

/s/ NEIL M. KOEHLER

Neil M. Koehler

President and Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the dates indicated.

Signature	Title	Date
/s/ WILLIAM L. JONES William L. Jones	Chairman of the Board and Director	March 15, 2018
/s/ NEIL M. KOEHLER Neil M. Koehler	President, Chief Executive Officer (Principal Executive Officer) and Director	March 15, 2018
/s/ BRYON T. MCGREGOR Bryon T. McGregor	Chief Financial Officer (Principal Financial and Accounting Officer)	March 15, 2018
/s/ MICHAEL D. KANDRIS Michael D. Kandris	Chief Operating Officer and Director	March 15, 2018
/s/ TERRY L. STONE Terry L. Stone	Director	March 15, 2018
/s/ JOHN L. PRINCE John L. Prince	Director	March 15, 2018
/s/ DOUGLAS L. KIETA Douglas L. Kieta	Director	March 15, 2018
/s/ LARRY D. LAYNE Larry D. Layne	Director	March 15, 2018

EXHIBITS FILED WITH THIS REPORT

Exhibit Number	Description*
10.5	Form of Employee Restricted Stock Agreement under 2016 Stock Incentive Plan
10.31	Amendment No. 1 to Credit Agreement dated March 1, 2017 among Pacific Ethanol Pekin, LLC, 1st Farm Credit Services, PCA and CoBank, ACB
21.1	Subsidiaries of the Registrant
23.1	Consent of Independent Registered Public Accounting Firm
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

(*) 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. 

EX-10.5

Exhibit 10.5

PACIFIC ETHANOL, INC. 

RESTRICTED STOCK AGREEMENT

THIS RESTRICTED STOCK AGREEMENT (this “Agreement”) dated and effective as of __________ (the “Grant Date”) by and between Pacific Ethanol, Inc., a Delaware corporation (the “Company”), and «First_Name» «Last_Name» (“Employee”) is entered into as follows:

WHEREAS, the Company has established the Pacific Ethanol, Inc. 2016 Stock Incentive Plan (the “Plan”), a copy of which has previously been provided to Employee or is provided with this Agreement; and

WHEREAS, the Compensation Committee of the Board of Directors of the Company (the “Committee”) has determined that Employee be granted shares of the Company’s $.001 par value per share Common Stock (the “Restricted Stock”) subject to the restrictions stated below.

Capitalized terms used but not otherwise defined herein shall have the respective meanings ascribed to them in the Plan. References herein to the Company shall also include, where and as applicable, any Parent or Subsidiary of the Company in the same manner used in the Plan.

NOW, THEREFORE, the parties hereby agree as follows:

1.            Grant of Restricted Stock. Subject to the terms and conditions of this Agreement and of the Plan, the Company hereby grants to Employee «First_Name» «Last_Name», «Total_of_Shares_in_Words» («Total_of_Shares») shares of Restricted Stock. As soon as practicable, the Company shall cause the shares of Restricted Stock to be issued in Employee’s name. During the Restriction Period (as defined below), the Restricted Stock shall be held in the custody of the Company or its designee for Employee’s account. The Restricted Stock shall be subject to, and shall bear appropriate legends with respect to, the restrictions described herein.

2.            Vesting Schedule.

(a)       The interest of Employee in the Restricted Stock shall vest as follows: 33% of the shares of Restricted Stock shall vest on ______, 20__, 33% of the shares of Restricted Stock shall vest on ______, 20__ and 34% of the shares of Restricted Stock shall vest on ______, 20__; provided, that Employee remains continuously employed by the Company on a full-time basis from the Grant Date through the applicable vesting date. If a vesting date falls on a weekend or any other day on which the NASDAQ Stock Market (“NASDAQ”) is not open, vesting of the corresponding Restricted Stock shall occur on the next following NASDAQ trading day. Notwithstanding the foregoing, the interest of Employee in the Restricted Stock may vest as to one hundred percent (100%) of the then unvested shares of Restricted Stock upon a Change in Control but only in accordance with the Plan.

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(b)       Upon termination of the Restriction Period, the Company shall, as soon as practicable thereafter, deliver instructions to American Stock Transfer (“AST”) to deposit and make available the number of shares of Restricted Stock with respect to which such restrictions have lapsed into the Employee’s Managed Shares account at AST or a brokerage company selected from time to time by the Company. Employee may instruct AST to deliver vested shares of Restricted Stock to Employee, or Employee’s broker or other designee; provided, that Employee communicates such instruction through the AST site not less than five (5) business days prior to the applicable vesting date. Employee may thereafter request delivery of the vested shares of Restricted Stock to Employee, or Employee’s broker or other designee in accordance with the terms and conditions applicable to Employee’s Managed Shares account.

3.            Restrictions.

(a)       No portion of the Restricted Stock or rights granted hereunder may be sold, transferred, assigned, pledged or otherwise encumbered or disposed of by Employee until such portion of the Restricted Stock becomes vested in accordance with Section 2 of this Agreement. The period of time between the date hereof and the date shares of Restricted Stock vest is referred to herein as the “Restriction Period” as to those shares of Restricted Stock. In addition, none of the Restricted Stock, even if vested, may be sold or transferred in contravention of (i) any market blackout periods the Company may impose from time to time, or (ii) the Company’s insider trading policies to the extent applicable to Employee from time to time.

(b)       The vesting schedule requires Employee’s continued service as a full-time employee of the Company during the applicable vesting periods as a condition to the vesting of the Restricted Stock and the rights and benefits under this Agreement. If Employee’s employment with the Company is terminated for any reason, whether voluntarily or involuntarily, the balance of the Restricted Stock subject to the provisions of this Agreement which has not vested at the time of Employee’s termination of employment shall be forfeited by Employee without payment of any consideration by the Company and neither Employee nor any successor, heir, assign or personal representative of Employee shall have any right, title or interest in or to the forfeited shares of Restricted Stock or the certificates evidencing them, and the Company shall direct its transfer agent of the Common Stock to make the appropriate entries in its records showing the cancellation of the certificate or certificates for such Restricted Stock. Service as an employee for only a portion of a vesting period, even if a substantial portion, will not entitle Employee to any proportionate vesting of the Restricted Stock allocated to that period or avoid or mitigate the forfeiture of Employee’s Restricted Stock that will occur upon the cessation of Employee’s service as an employee of the Company. Notwithstanding the foregoing, the Company may, by written agreement with the Employee, expressly agree to provisions different from those set forth above with respect to severance benefits as to the Restricted Stock.

4.            Shareholder Rights. During the Restriction Period, Employee shall have all the rights of a shareholder with respect to the Restricted Stock except for the right to transfer the Restricted Stock, as set forth in Section 3 of this Agreement. Accordingly, Employee shall have the right to vote the Restricted Stock and to receive any cash dividends paid to or made with respect to the Restricted Stock; provided, however, that dividends paid, if any, with respect to that Restricted Stock which has not vested at the time of the dividend payment shall be held in the custody of the Company and shall be subject to the same restrictions that apply to the corresponding Restricted Stock.

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5.            Changes in Common Stock. If any change is made to the Common Stock by reason of any stock split, stock dividend, recapitalization, combination of shares, exchange of shares or other change affecting the outstanding Common Stock as a class without the Company’s receipt of consideration, appropriate adjustments shall be made by the Plan Administrator to (i) the maximum number and/or class of securities issuable under the Plan, (ii) the maximum number and/or class of securities for which any one person may be granted Awards under the Plan per calendar year, (iii) the number and/or class of securities and the exercise or base price per share (or any other cash consideration payable per share) in effect under each outstanding Award under the Discretionary Grant Program, and (iv) the number and/or class of securities subject to each outstanding Award under the Stock Issuance Program and the cash consideration (if any) payable per share thereunder. To the extent such adjustments are to be made to outstanding Awards, those adjustments shall be effected in a manner that shall preclude the enlargement or dilution of rights and benefits under those Awards. The adjustments determined by the Plan Administrator shall be final, binding and conclusive.

6.            Taxes.

(a)       Employee will recognize ordinary income for federal income tax purposes on each date the Restricted Stock subject to Employee’s award vests, whether pursuant to the normal vesting schedule above, the acceleration provisions of this Agreement that may apply or otherwise. The amount of Employee’s taxable income on each such vesting date will equal the fair market value per share of Common Stock on the date of vesting times the number of shares of Restricted Stock which vest on that date.

(b)       Employee shall be liable for any and all taxes, including any withholding taxes, arising out of this grant or the vesting of Restricted Stock hereunder. Employee may elect to satisfy such withholding tax obligation by (i) having the Company retain Restricted Stock having a fair market value equal to the Company’s minimum withholding obligation, or (ii) making a cash payment to the Company in an amount equal to the Company’s minimum withholding obligation; provided, that Employee make and communicate such election through the AST site as to the applicable vesting amount not less than five (5) business days prior to the applicable vesting date. If Employee elects to pay the applicable minimum withholding amount in cash, then Employee shall make such payment within two (2) business days following the applicable vesting date. If Employee (A) fails to make and communicate such election through the AST site within the applicable time period, or (B) elects to make a cash payment of the minimum withholding amount and Employee fails to make such payment within two (2) business days following the applicable vesting date, then the Company’s minimum withholding tax obligations shall be satisfied by the Company withholding a number of shares of Restricted Stock that would otherwise vest and be delivered to Employee under this Agreement that the Company determines has a fair market value sufficient to meet such obligations. The Company shall not be required to deliver any Restricted Stock or to recognize any purported transfer of shares of the Restricted Stock until such withholding obligations are satisfied. Employee is ultimately liable and responsible for all taxes owed by Employee in connection with Employee’s Restricted Stock, regardless of any action the Company takes with respect to any tax withholding obligations that arise in connection with the Restricted Stock. The Company makes no representation or undertaking regarding the treatment of any tax withholding in connection with the grant, issuance, vesting or settlement of the Restricted Stock or the subsequent sale of any of the shares of Restricted Stock. The Company does not commit and is under no obligation to structure the Restricted Stock award or program to reduce or eliminate Employee’s tax liability. The Company shall not be required to issue or deliver to Employee fractional shares of Restricted Stock upon withholding of any shares of Restricted Stock to cover the minimum withholding tax, or otherwise, and any fractional share amounts shall be paid to Employee by the Company solely in cash based on the pro rata fair market value of such fractional share amounts on the date of vesting.

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7.            Securities Law Compliance. The Company will use its reasonable commercial efforts to assure that all Restricted Stock issued pursuant to this Agreement is registered under the federal securities laws. However, no Restricted Stock will be issued pursuant to Employee’s award if such issuance would otherwise constitute a violation of any applicable federal or state securities laws or regulations or the requirements of The NASDAQ Capital Market and any stock exchange or other market on which the Common Stock is then quoted or listed for trading. The inability of the Company to obtain approval from any regulatory body having authority deemed by the Company to be necessary to the lawful issuance of any Restricted Stock hereunder shall defer the Company’s obligation with respect to the issuance of such Restricted Stock until such approval has been obtained.

8.            Miscellaneous.

(a)       The grant of Restricted Stock or another award to Employee in any one year, or at any time, does not obligate the Company to make a grant in any future year or in any given amount and should not create an expectation that the Company might make a grant in any future year or in any given amount.

(b)       The Company shall not be required (i) to transfer on its books any shares of Restricted Stock which shall have been sold or transferred in violation of any of the provisions set forth in this Agreement, or (ii) to treat as owner of such shares or to accord the right to vote as such owner or to pay dividends to any transferee to whom such shares shall have been so transferred.

(c)       The parties agree to execute such further instruments and to take such action as may reasonably be necessary to carry out the intent of this Agreement.

(d)       Any notice required or permitted hereunder shall be given in writing and shall be deemed effectively given upon delivery to Employee at Employee’s address then on file with the Company.

(e)       This Agreement shall not be construed so as to grant Employee any right to remain in the employ of the Company.

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(f)       The parties agree that neither the Company nor any of its affiliates shall have any further obligation to Employee relating to the grant of stock or other incentive compensation except as stated herein.

(g)       This Agreement and the Plan constitute the entire agreement of the parties with respect to the subject matter hereof. This Agreement may not be amended except with the consent of the Committee and by a written instrument duly executed by the Company and Employee.

(h)       This Agreement shall be binding upon and shall inure to the benefit of the parties hereto and to their heirs, personal representatives, successors and assigns. The terms of this Agreement shall in all respects be subject to the terms of the Plan. Employee hereby agrees to accept as binding, conclusive and final all decisions and interpretations of the Committee upon any questions arising under the Plan or this Agreement.

(i)       The interpretation, performance and enforcement of this Agreement shall be governed by the laws of the State of Delaware without resort to that State’s conflicts-of-laws rules.

(j)       This Agreement shall not in any way affect the right of the Company to adjust, reclassify, reorganize or otherwise make changes in its capital or business structure or to merge, consolidate, dissolve, liquidate or sell or transfer all or any part of its business or assets.

9.            Mandatory Arbitration. ANY AND ALL DISPUTES OR CONTROVERSIES BETWEEN EMPLOYEE AND THE COMPANY OR BETWEEN THE COMPANY AND EMPLOYEE ARISING OUT OF, RELATING TO OR OTHERWISE CONNECTED WITH THIS AGREEMENT OR THE AWARD OF RESTRICTED STOCK EVIDENCED HEREBY OR THE VALIDITY, CONSTRUCTION, PERFORMANCE OR TERMINATION OF THIS AGREEMENT SHALL BE SETTLED EXCLUSIVELY BY BINDING ARBITRATION TO BE HELD IN SACRAMENTO COUNTY, CALIFORNIA. THE ARBITRATION PROCEEDINGS SHALL BE GOVERNED BY (I) THE NATIONAL RULES FOR THE RESOLUTION OF EMPLOYMENT DISPUTES THEN IN EFFECT OF THE AMERICAN ARBITRATION ASSOCIATION, AND (II) THE FEDERAL ARBITRATION ACT. THE ARBITRATOR SHALL HAVE THE SAME, BUT NO GREATER, REMEDIAL AUTHORITY AS WOULD A COURT HEARING THE SAME DISPUTE. THE DECISION OF THE ARBITRATOR SHALL BE FINAL, CONCLUSIVE AND BINDING ON THE PARTIES TO THE ARBITRATION AND SHALL BE IN LIEU OF THE RIGHTS THOSE PARTIES MAY OTHERWISE HAVE TO A JURY TRIAL; PROVIDED, HOWEVER, THAT SUCH DECISION SHALL BE SUBJECT TO CORRECTION, CONFIRMATION OR VACATION IN ACCORDANCE WITH THE PROVISIONS AND STANDARDS OF APPLICABLE LAW GOVERNING THE JUDICIAL REVIEW OF ARBITRATION AWARDS. THE ARBITRATOR SHALL ISSUE A WRITTEN DECISION THAT REVEALS THE ESSENTIAL FINDINGS AND CONCLUSIONS ON WHICH THE DECISION IS BASED, AND THE ARBITRATOR’S DECISION SHALL BE SUBJECT TO SUCH JUDICIAL REVIEW AS IS PROVIDED BY LAW. THE COMPANY SHALL PAY ANY ARBITRATION FILING FEE, AND WILL BEAR ALL OTHER COSTS OF ARBITRATION, INCLUDING FEES FOR THE SERVICES OF THE ARBITRATOR AND ANY COURT REPORTER ORDERED BY THE ARBITRATOR. EACH PARTY SHALL BEAR ITS, HIS OR HER OWN COSTS OF LEGAL REPRESENTATION; PROVIDED, HOWEVER, IF ANY PARTY PREVAILS ON A CLAIM ENTITLING THE PREVAILING PARTY TO ATTORNEYS’ FEES AND/OR COSTS PURSUANT TO ANY APPLICABLE EMPLOYMENT OR CIVIL RIGHTS STATUTE, THE ARBITRATOR MAY AWARD REASONABLE FEES AND/OR COSTS TO THE PREVAILING PARTY IN ACCORDANCE WITH SUCH CLAIM. JUDGMENT SHALL BE ENTERED ON THE ARBITRATOR’S DECISION IN ANY COURT HAVING JURISDICTION OVER THE SUBJECT MATTER OF SUCH DISPUTE OR CONTROVERSY. NOTWITHSTANDING THE FOREGOING, EITHER PARTY MAY IN AN APPROPRIATE MATTER APPLY TO A COURT PURSUANT TO CALIFORNIA CODE OF CIVIL PROCEDURE SECTION 1281.8, OR ANY COMPARABLE STATUTORY PROVISION OR COMMON LAW PRINCIPLE, FOR PROVISIONAL RELIEF, INCLUDING A TEMPORARY RESTRAINING ORDER OR A PRELIMINARY INJUNCTION. TO THE EXTENT PERMITTED BY LAW, THE PROCEEDINGS AND RESULTS, INCLUDING THE ARBITRATOR’S DECISION, SHALL BE KEPT CONFIDENTIAL TO THE EXTENT PERMITTED BY APPLICABLE LAW.

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10.          Remaining Terms. The remaining terms and conditions of Employee’s award are governed by the Plan, and Employee’s award is also subject to all interpretations, amendments, rules, regulations and decisions that may from time to time exist, be adopted or made under and pursuant to the Plan. The General Plan Description, which is the official prospectus summarizing the principal features of the Plan, has previously been provided to Employee or is provided with this Agreement.

(Signature Page Follows)

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IN WITNESS WHEREOF, the undersigned have executed this Agreement effective on the date first set above.

COMPANY:	PACIFIC ETHANOL, INC.,
	a Delaware corporation
	By:

I, the undersigned Employee, hereby acknowledge receiving, reading and understanding the General Plan Description, which is the official prospectus summarizing the principal features of the Plan, this Agreement and the Plan itself. I further acknowledge and accept the foregoing terms and conditions of the Restricted Stock award evidenced hereby. I also acknowledge and agree that the foregoing sets forth the entire understanding between the Company and me regarding my entitlement to receive the shares of the Company’s Common Stock subject to such award and supersedes all prior oral and written agreements on that subject.

EMPLOYEE:
	«First_Name» «Last_Name»

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NOTICE OF ELECTION

Chief Financial Officer

Pacific Ethanol, Inc.

Re: Notice of Election as to Manner of Payment of Minimum Withholding Tax

1.           The undersigned Employee has been granted shares of Restricted Stock of Pacific Ethanol, Inc., a Delaware corporation (the “Company”).

2.           The undersigned Employee hereby elects to (check one):

_____ pay the minimum withholding tax in cash with respect to shares of Restricted Stock; or

_____ have shares of Restricted Stock withheld by the Company to cover the minimum withholding tax.

3.           The foregoing election is with respect to the following Grant Date or vesting date(check one):

_____ ________, 20__

_____ ________, 20__

_____ ________, 20__

4.           If the undersigned Employee has elected to pay to the Company the minimum withholding tax in cash with respect to shares of Restricted Stock, the undersigned Employee shall make such payment to the Company within two (2) business days following the applicable vesting date. If the undersigned Employee fails to make payment within such period, then the Company’s minimum withholding tax obligations may be satisfied by the Company withholding a number of shares of Restricted Stock that would otherwise vest and be delivered to Employee that the Company determines has a fair market value sufficient to meet such obligations.

5.           The terms and conditions of Company’s grant of Restricted Stock are governed solely by the Restricted Stock Agreement and the Plan.

Dated:	EMPLOYEE
	«First_Name» «Last_Name»

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EX-10.31

Exhibit 10.31

AMENDMENT NO. 1

TO

CREDIT AGREEMENT

THIS AMENDMENT NO. 1 TO CREDIT AGREEMENT, dated as of March 1, 2017 (this “Agreement”), is entered into by and between PACIFIC ETHANOL PEKIN, LLC, a limited liability company organized and existing under the laws of Delaware (“Company”), 1^ST FARM CREDIT SERVICES, PCA, a federally-chartered instrumentality of the United States (“Lender”), and COBANK, ACB, a federally-chartered instrumentality of the United States (“CoBank” or “Agent”). Capitalized terms not defined herein shall have the meanings set forth in the Existing Credit Agreement.

BACKGROUND:

WHEREAS, the Company, Lender and CoBank have entered into that certain Credit Agreement dated as of December 15, 2016 (as the same may from time to time be amended, restated, modified or otherwise supplemented, collectively the “Existing Credit Agreement”), and the other Loan Documents;

WHEREAS, at the time the Credit Agreement was entered into, the Company was a corporation organized and existing under the laws of Delaware and its legal name was “Pacific Ethanol Pekin, Inc.”;

WHEREAS, on January 31, 2017, the Company converted to a limited liability company organized and existing under the laws of Delaware and its legal name was changed to “Pacific Ethanol Pekin, LLC”;

WHEREAS, the Company has requested that certain of the deadlines set forth under Section 6.12 of the Existing Credit Agreement be extended;

WHEREAS, the Company has requested that, as of the Effective Date, the Existing Credit Agreement be amended as herein provided; and

WHEREAS, CoBank is willing, subject to the terms and conditions hereinafter set forth, to make such amendments;

NOW, THEREFORE, in consideration of the agreements herein contained, the parties hereby agree as follows:

ARTICLE 1         Definitions.

1.1           Certain Definitions. The following terms when used in the Agreement shall have the following meanings:

“Agreement” is defined in the preamble to this Agreement.

“CoBank” is defined in the preamble to this Agreement.

“Company” is defined in the preamble to this Agreement.

“Effective Date” is defined in Article 4.

“Entity Conversion” means, collectively, the Company’s (a) conversion from a Delaware corporation to a Delaware limited liability company and (b) change in name from “Pacific Ethanol Pekin, Inc.” to “Pacific Ethanol Pekin, LLC”.

“Existing Credit Agreement” is defined in the first recital to this Agreement.

1.2           Other Definitions. Unless otherwise defined or the context otherwise requires, terms used herein (including in the preamble and recitals hereto) have the meanings provided for in the Existing Credit Agreement.

ARTICLE 2         Amendments.

Effective on (and subject to the occurrence of) the Effective Date, the Existing Credit Agreement is amended as follows:

2.1           Company Conversion. The Credit Agreement is hereby amended to reflect that effective as of January 31, 2017, (a) the Company is a limited liability company organized and existing under the laws of Delaware and (b) the Company’s legal name is “Pacific Ethanol Pekin, LLC”.

2.2           Amendment to Section 6.12 of the Existing Credit Agreement. Section 6.12 of the Existing Credit Agreement is hereby amended by deleting Section 6.12 in its entirety and substituting the following Section 6.12 in its place:

“6.12       Additional Items. The Company shall provide Agent with each of the following (which, in the case of instruments and documents, must (unless otherwise stated below) be originals, duly executed, and in form and substance satisfactory to Agent), on or before the date indicated:

(a)          The Title Policy, on or before March 1, 2017;

(b)          An executed collateral assignment, subordination agreement or other similar agreement from the Persons party to any agreement with the Company set forth on the attached Schedule 6.12(b), on or before April 1, 2017;

(c)          A control agreement in respect of each Brokerage Account maintained by the Company, in each case properly executed on behalf of each of the parties thereto, on or before March 1, 2017;

(d)          Survey and subdivision of any portion of the Real Property Collateral requested by Agent or Lender for the purpose of Lender releasing its Lien for any such portion of the Real Estate Collateral as Lender may desire, at any time at the request of Agent or Lender; and

(e)          Payment of all fees and expenses of Agent and the Lending Parties, if any, as required by this Agreement or any other Loan Document, on or before April 1, 2017.”

ARTICLE 3         Representations and Warranties.

In order to induce CoBank to make the amendments provided for in Article 2, the Company hereby (a) represents and warrants that (i) each of the representations and warranties of the Company contained in the Existing Credit Agreement and in the other Loan Documents are true and correct in all material respects on and as of the date hereof, except that such representations and warranties (A) that relate solely to an earlier date shall be true and correct in all material respects as of such earlier date, (B) shall be true and correct in all respects to the extent they are qualified by a materiality standard and (C) shall be true and correct in all respects to the extent they are qualified by the amendments provided for in Section 2.1 hereof and (ii) no Default or Event of Default has occurred and is continuing; and (b) agrees that the incorrectness in any respect of any representation and warranty contained in the preceding clause (a) shall constitute an immediate Event of Default. Without limiting the foregoing, the Company hereby (x) ratifies and confirms all of the terms, covenants and conditions set forth in the Loan Documents and hereby agrees that it remains unconditionally liable to CoBank in accordance with the respective terms, covenants and conditions set forth in the Loan Documents, and all Collateral in favor of CoBank continues unimpaired and in full force and effect, and (y) waives all defense, claims, counterclaims, rights of recoupment or set-off against any of its obligations.

ARTICLE 4         Conditions to Effectiveness.

This Agreement shall become effective on such date (the “Effective Date”) when the following conditions have been satisfied:

4.1          Representations and Warranties. The representations and warranties made by the Company pursuant to Article 3 as of the Effective Date shall be true and correct.

4.2          Other Requests. CoBank shall have received such other certificates, instruments, documents, agreements, information and reports as may be requested by CoBank, in form and substance satisfactory to CoBank, including, but not limited to, the following on or before the dates indicated:

(a)          Fully-executed and filed (as applicable) copies of all documents relating to the Entity Conversion, on or before April 1, 2017;

(b)          All amendments to the Loan Documents requested by Agent in connection with the Entity Conversion, on or before April 1, 2017;

(c)          A Secretary’s Certificate with attached organizational documents, good standing certificates, resolutions and incumbency certificate, on or before April 1, 2017;

(d)          Any endorsements to the Title Policy requested by Agent as a result of the Entity Conversion, on or before April 1, 2017;

(e)          A non-refundable consent fee equal to Three Thousand Five Hundred Dollars ($3,500) in connection with the Entity Conversion, on or before April 1, 2017; and

(f)          All fees and expenses incurred by Agent in connection with the Entity Conversion, including any amendments, modifications, UCC filings, title policy endorsements and real estate recording costs, on or before April 1, 2017.

The items set forth in this Section 4.2(a)-(f) supplement and replace the requirements set forth in that certain Written Consent dated January 30, 2017 executed by Agent in favor of the Company.

ARTICLE 5         Miscellaneous.

5.1          Loan Document Pursuant to Existing Credit Agreement. This Agreement is a Loan Document executed pursuant to the Existing Credit Agreement. Except as expressly amended hereby, all of the representations, warranties, terms, covenants and conditions contained in the Existing Credit Agreement and each other Loan Document shall remain unamended an otherwise unmodified and in full force and effect.

5.2          Limitation of Amendments. The amendments set forth in Article 2 shall be limited precisely as provide for herein and shall not be deemed to be a waiver of, amendment of, consent to or modification of any other term or provision of the Existing Credit Agreement or any term or provision of any other Loan Document or of any transaction or further or future action on the part of the Company which would require the consent of CoBank under the Existing Credit Agreement or any other Loan Document.

5.3          Incorporation of Existing Credit Agreement Provisions. The provisions of Article 11 of the Existing Credit Agreement shall apply to this Agreement, mutatis mutandis.

[Signature Pages Follow]

[SIGNATURE PAGE TO CREDIT AGREEMENT AMENDMENT]

IN WITNESS WHEREOF, the parties hereto, by their Authorized Officers, have executed this Agreement as of the date first set forth above.

COMPANY:
PACIFIC ETHANOL PEKIN, LLC
By:	/s/ Bryon T. McGregor
Name:	Bryon T. McGregor
Title:	Chief Financial Officer

[SIGNATURE PAGE TO CREDIT AGREEMENT AMENDMENT]

IN WITNESS WHEREOF, the parties hereto, by their Authorized Officers, have executed this Agreement as of the date first set forth above.

lender:
1ST FARM CREDIT SERVICES, PCA
By:	/s/ Dale A. Richardson
Name:	Dale A. Richardson
Title:	Vice President, Capital Markets Group

[SIGNATURE PAGE TO CREDIT AGREEMENT AMENDMENT]

IN WITNESS WHEREOF, the parties hereto, by their Authorized Officers, have executed this Agreement as of the date first set forth above.

COBANK, ACB
By:	/s/ Tom D. Houser
Name:	Tom D. Houser
Title:	Vice President

EX-21.1

EXHIBIT 21.1

SUBSIDIARIES OF THE REGISTRANT

Subsidiary Name*	Name(s) Under Which  Subsidiary Does Business**	State or Jurisdiction of Incorporation or Organization
Kinergy Marketing LLC	−	Oregon
Pacific Ag. Products, LLC	PAP	California
Pacific Ethanol Development, LLC	−	Delaware
PE Op Co.	−	Delaware
Pacific Ethanol West, LLC	−	Delaware
Pacific Ethanol Columbia, LLC	−	Delaware
Pacific Ethanol Madera LLC	−	Delaware
Pacific Ethanol Magic Valley, LLC	−	Delaware
Pacific Ethanol Stockton LLC	−	Delaware
Pacific Ethanol Central, LLC	−	Delaware
Pacific Ethanol Canton, LLC	−	Delaware
Pacific Ethanol Pekin, LLC	−	Delaware
Pacific Aurora, LLC(1)	−	Delaware
Pacific Ethanol Aurora East, LLC(1)	−	Delaware
Pacific Ethanol Aurora West, LLC(1)	−	Delaware
Illinois Corn Processing, LLC	−	Delaware

* All subsidiaries are directly or indirectly wholly-owned by the Registrant unless otherwise specified by footnote.

** If different from the name of the subsidiary.

(1) The Registrant indirectly holds a 73.93% ownership interest in Pacific Aurora, LLC, which owns Pacific Ethanol Aurora East, LLC and Pacific Ethanol Aurora West, LLC.

EX-23.1

Exhibit 23.1

Consent of Independent Registered Public Accounting Firm

We consent to the incorporation by reference in Registration Statement (Nos. 333-137663, 333-169002, 333-176540, 333-185884, 333-189478, 333-196876 and 333-212070) on Form S-8 and (No. 333-217323) on Form S-3 and (No. 333-201879) on Form S-4, of Pacific Ethanol, Inc. of our reports dated March 15, 2018, relating to the consolidated financial statements and the effectiveness of internal control over financial reporting of Pacific Ethanol, Inc., appearing in this Annual Report on Form 10-K of Pacific Ethanol, Inc. for the year ended December 31, 2017.

/s/ RSM US LLP

Sioux Falls, South Dakota

March 15, 2018

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 Annual Report on Form 10-K 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 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: March 15, 2018	/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 Annual Report on Form 10-K 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 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: March 15, 2018	/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 Annual Report on Form 10-K of Pacific Ethanol, Inc. (the “Company”) for the period ended December 31, 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:   March 15, 2018	By:	/S/ NEIL M. KOEHLER
		Neil M. Koehler
		President and Chief Executive Officer (Principal Executive Officer)

Dated:   March 15, 2018	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.

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Document and Entity Information - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Mar. 14, 2018	Jun. 30, 2017
Document And Entity Information
Entity Registrant Name	Pacific Ethanol, Inc.
Entity Central Index Key	0000778164
Document Type	10-K
Trading Symbol	PEIX
Document Period End Date	Dec. 31, 2017
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity a Well-known Seasoned Issuer	No
Entity a Voluntary Filer	No
Entity's Reporting Status Current	Yes
Entity Filer Category	Accelerated Filer
Entity Public Float			$ 266,300
Entity Common Stock, Shares Outstanding		43,959,245
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2017

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CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Current Assets:
Cash and cash equivalents	$ 49,489	$ 64,259
Accounts receivable, net of allowance for doubtful accounts of $19 and $331, respectively	80,344	86,275
Inventories	61,550	60,070
Prepaid inventory	3,281	9,946
Income tax receivables	743	5,730
Derivative assets	998	978
Other current assets	6,841	7,943
Total current assets	203,246	235,201
Property and equipment, net	508,352	465,190
Other Assets:
Intangible assets	2,678	2,678
Other assets	6,020	5,169
Total other assets	8,698	7,847
Total Assets	720,296	708,238
Current Liabilities:
Accounts payable - trade	39,738	37,051
Accrued liabilities	21,673	20,280
Current portion - capital leases	592	794
Current portion - long-term debt	20,000	10,500
Derivative liabilities	2,307	4,115
Other current liabilities	6,396	6,101
Total current liabilities	90,706	78,841
Long-term debt, net of current portion	221,091	188,028
Capital leases, net of current portion	123	547
Warrant liabilities at fair value		651
Other liabilities	24,676	21,910
Total Liabilities	336,596	289,977
Commitments and contingencies (Notes 1, 8, 9 and 14)
Stockholders' Equity:
Common stock value	44	40
Additional paid-in capital	927,090	922,698
Accumulated other comprehensive loss	(2,234)	(2,620)
Accumulated deficit	(568,462)	(532,233)
Total Pacific Ethanol, Inc. stockholders' equity	356,439	387,890
Noncontrolling interests	27,261	30,371
Total stockholders' equity	383,700	418,261
Total Liabilities and Stockholders' Equity	720,296	708,238
Series A Preferred Stock
Stockholders' Equity:
Preferred stock, $0.001 par value; 10,000,000 shares authorized: Series A: 1,684,375 shares authorized; no shares issued and outstanding as of December 31, 2017 and 2016 Series B: 1,580,790 shares authorized; 926,942 shares issued and outstanding as of December 31, 2017 and 2016; liquidation preference of $18,075 as of December 31, 2017
Series B Preferred Stock
Stockholders' Equity:
Preferred stock, $0.001 par value; 10,000,000 shares authorized: Series A: 1,684,375 shares authorized; no shares issued and outstanding as of December 31, 2017 and 2016 Series B: 1,580,790 shares authorized; 926,942 shares issued and outstanding as of December 31, 2017 and 2016; liquidation preference of $18,075 as of December 31, 2017	1	1
Nonvoting Common Stock [Member]
Stockholders' Equity:
Common stock value		$ 4

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CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Accounts receivable, net of allowance	$ 19	$ 331
Preferred stock par value	$ 0.001	$ 0.001
Preferred stock shares authorized	10,000,000	10,000,000
Common stock, par value	$ 0.001	$ 0.001
Common stock, authorized	300,000,000	300,000,000
Common stock, issued	43,984,975	39,772,238
Common stock, outstanding	43,984,975	39,772,238
Series A Preferred Stock
Preferred stock shares authorized	1,684,375	1,684,375
Preferred stock shares issued	0	0
Preferred stock shares outstanding	0	0
Series B Preferred Stock
Preferred stock shares authorized	1,580,790	1,580,790
Preferred stock shares issued	926,942	926,942
Preferred stock shares outstanding	926,942	926,942
Preferred stock liquidation preference	$ 18,075
Nonvoting Common Stock [Member]
Common stock, par value	$ 0.001	$ 0.001
Common stock, authorized	3,553,000	3,553,000
Common stock, issued	896	3,540,132
Common stock, outstanding	896	3,540,132

XML

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Statement [Abstract]
Net sales	$ 1,632,255	$ 1,624,758	$ 1,191,176
Cost of goods sold	1,626,324	1,570,400	1,180,810
Gross profit	5,931	54,358	10,366
Selling, general and administrative expenses	31,516	30,849	26,368
Asset impairment			1,970
Income (loss) from operations	(25,585)	23,509	(17,972)
Fair value adjustments and warrant inducements	473	(557)	1,641
Interest expense	(12,938)	(22,406)	(12,594)
Other income (expense), net	(345)	(1)	18
Income (loss) before provision for income taxes	(38,395)	545	(28,907)
Provision (benefit) for income taxes	(321)	(981)	(10,034)
Consolidated net income (loss)	(38,074)	1,526	(18,873)
Net (income) loss attributed to noncontrolling interests	3,110	(107)	87
Net income (loss) attributed to Pacific Ethanol, Inc.	(34,964)	1,419	(18,786)
Preferred stock dividends	(1,265)	(1,269)	(1,265)
Income allocated to participating securities		(2)
Income (loss) available to common stockholders	$ (36,229)	$ 148	$ (20,051)
Income (loss) per share, basic and diluted	$ (0.85)	$ 0.00	$ (0.6)
Weighted-average shares outstanding, basic	42,745	42,182	33,173
Weighted-average shares outstanding, diluted	42,745	42,251	33,173

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Statement of Comprehensive Income [Abstract]
Consolidated net income (loss)	$ (38,074)	$ 1,526	$ (18,873)
Other comprehensive income (expense) - net gain (loss) arising during the period on defined benefit pension plans	386	(3,660)	1,040
Total comprehensive loss	(37,688)	(2,134)	(17,833)
Comprehensive (income) loss attributed to noncontrolling interests	3,110	(107)	87
Comprehensive loss attributed to Pacific Ethanol, Inc.	$ (34,578)	$ (2,241)	$ (17,746)

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CONSOLIDATED STATEMENTS OF STOCKHOLDERS EQUITY - USD ($) $ in Thousands	Preferred Stock [Member]	Common Stock [Member]	Additional Paid-In Capital [Member]	Accumulated Deficit [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Noncontrolling Interest [Member]	Total
Balance at Beginning at Dec. 31, 2014	$ 1	$ 25	$ 725,813	$ (512,332)		$ 4,475	$ 217,982
Balance at Beginning (in shares) at Dec. 31, 2014	927	24,499
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock-based compensation expense - restricted stock issued to employees and directors, net of cancellations and tax			1,475				1,475
Stock-based compensation expense - restricted stock issued to employees and directors, net of cancellations and tax (in shares)		216
Pension plan adjustment					1,040		(1,040)
Warrant and option exercises			440				440
Warrant and option exercises (in shares)		42
Shares issued in PE Central acquisition		$ 18	174,555				174,573
Shares issued in PE Central acquisition (in shares)		17,758
Purchases of interests in PE Op Co.			560			(4,388)	(3,828)
Preferred stock dividends				(1,265)			1,265
Net loss				(18,786)		(87)	(18,873)
Balance at End at Dec. 31, 2015	$ 1	$ 43	902,843	(532,383)	1,040		371,544
Balance at End (in shares) at Dec. 31, 2015	927	42,515
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock-based compensation expense - restricted stock issued to employees and directors, net of cancellations and tax		$ 1	2,281				2,282
Stock-based compensation expense - restricted stock issued to employees and directors, net of cancellations and tax (in shares)		659
Pension plan adjustment					(3,660)		3,660
Warrant and option exercises			1,338				1,338
Warrant and option exercises (in shares)		138
Preferred stock dividends				(1,269)			1,269
Sale of Pacific Aurora interests to ACEC			10,475			19,525	30,000
ACEC contribution to form Pacific Aurora			5,761			10,739	16,500
Net loss				1,419		107	1,526
Balance at End at Dec. 31, 2016	$ 1	$ 44	922,698	(532,233)	(2,620)	30,371	418,261
Balance at End (in shares) at Dec. 31, 2016	927	43,312
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock-based compensation expense - restricted stock issued to employees and directors, net of cancellations and tax			3,014				3,014
Stock-based compensation expense - restricted stock issued to employees and directors, net of cancellations and tax (in shares)		473
Pension plan adjustment					386		(386)
Warrant and option exercises			1,378				1,378
Warrant and option exercises (in shares)		201
Preferred stock dividends				(1,265)			1,265
Net loss				(34,964)		(3,110)	(38,074)
Balance at End at Dec. 31, 2017	$ 1	$ 44	$ 927,090	$ (568,462)	$ (2,234)	$ 27,261	$ 383,700
Balance at End (in shares) at Dec. 31, 2017	927	43,986

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CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operating Activities:
Consolidated net income (loss)	$ (38,074)	$ 1,526	$ (18,873)
Adjustments to reconcile consolidated net income (loss) to cash provided by (used in) operating activities:
Depreciation and amortization of intangibles	38,651	35,441	23,632
Fair value adjustments	(473)	557	(1,641)
Asset impairment			1,970
Deferred income taxes	169	(1,122)	(2,023)
Inventory valuation	2,678		509
Change in fair value on commodity derivative instruments	2,077	1,984	542
Amortization of deferred financing costs	503	137	272
Amortization of debt discounts	636	2,322	716
Noncash compensation	3,828	2,616	2,019
Bad debt expense (recovery)	5	306	(354)
Interest expense added to plant term debt		9,451
Changes in operating assets and liabilities, net of effects from acquisitions:
Accounts receivable	17,562	(25,235)	(15,950)
Inventories	5,070	750	(13,296)
Prepaid expenses and other assets	2,677	3,189	(1,093)
Prepaid inventory	6,738	(3,973)	5,622
Accounts payable and accrued expenses	(5,538)	9,279	(10,045)
Net cash provided by (used in) operating activities	36,509	37,228	(27,993)
Investing Activities:
Additions to property and equipment	(20,866)	(19,171)	(20,507)
Purchase of ICP, net of cash acquired	(29,574)
Proceeds (payments) for cash collateralized letters of credit		4,574	(4,574)
Net cash from acquisition of PE Central			18,756
Net cash used in investing activities	(50,440)	(14,597)	(6,325)
Financing Activities:
Proceeds from warrant and option exercises	1,202	1,164	368
Proceeds from plant term and revolving credit agreements	42,000	97,000
Proceeds from parent notes	13,530	53,350
Sale of noncontrolling interests		30,000
Proceeds from assessment financing	5,618	2,096
Net proceeds (payments) on Kinergy's line of credit	(385)	(11,141)	43,584
Payments on plant borrowings	(59,927)	(172,073)	(13,833)
Debt issuance costs	(986)	(1,960)
Preferred stock dividend payments	(1,265)	(1,269)	(1,265)
Payments on capital leases	(626)	(7,089)	(5,059)
Net cash provided by (used in) financing activities	(839)	(9,922)	23,795
Net increase (decrease) in cash and cash equivalents	(14,770)	12,709	(10,523)
Cash and cash equivalents at beginning of period	64,259	51,550	62,073
Cash and cash equivalents at end of period	49,489	64,259	51,550
Supplemental Information:
Interest paid	11,133	11,168	11,685
Income tax refunds	5,614	4,784	5,710
Noncash financing and investing activities:
Accrued payment for ownership positions of PE Op Co.			3,828
Capital leases added to plant and equipment	180		1,864
Reclass of warrant liability to equity upon exercises	178	179	72
Contribution of property and equipment for noncontrolling interest (see Note 2)		16,500
Debt issued in ICP acquisition (see Note 2)	46,927
Common stock issued in PE Central acquisition (see Note 2)			$ 174,573

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ORGANIZATION AND SIGNIFICANT ACCOUNTING POLICIES.

12 Months Ended

Dec. 31, 2017

Organization, Consolidation and Presentation of Financial Statements [Abstract]

ORGANIZATION AND SIGNIFICANT ACCOUNTING POLICIES.

1. ORGANIZATION AND SIGNIFICANT ACCOUNTING POLICIES.

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”) and PE Op Co., a Delaware corporation (“PE Op Co.”). 

The Company’s acquisition of Aventine Renewable Energy Holdings, Inc. (now, Pacific Ethanol Central, LLC, a Delaware limited liability company, “PE Central”) was consummated on July 1, 2015, and as a result, the Company’s consolidated financial statements include the results of PE Central only as of and for the years ended December 31, 2017 and 2016 and for the six months ended December 31, 2015. 

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, the Company owned 73.93% of Pacific Aurora and ACEC owned 26.07% of Pacific Aurora as of December 31, 2017 and 2016. Further, the Company has consolidated 100% of the results of Pacific Aurora and recorded ACEC’s 26.07% equity interest as noncontrolling interests in the accompanying financial statements for the year ended December 31, 2017 and for the period December 15, 2016 through December 31, 2016. 

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 only for the period from July 3, 2017 through December 31, 2017. 

The Company is a leading producer and marketer of low-carbon renewable fuels in the United States. 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. 

With the addition of four Midwestern ethanol plants in July 2015 as a result of the Company’s acquisition of PE Central and the addition of ICP’s plant in July 2017, the Company now has a combined production capacity of 605 million gallons per year, markets, on an annualized basis, nearly 1.0 billion gallons of ethanol and specialty alcohols, and produces, on an annualized basis, over 3.0 million tons of co-products on a dry matter basis, 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 allows for greater access to international markets. 

As of December 31, 2017, all nine facilities were operating. As market conditions change, the Company may increase, decrease or idle production at one or more operational facilities or resume operations at any idled facility. 

Basis of Presentation – The consolidated financial statements and related notes have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) and include the accounts of the Company. All significant intercompany accounts and transactions have been eliminated in consolidation. 

Segments – A segment is a component of an enterprise whose operating results are regularly reviewed by the enterprise’s chief operating decision maker to make decisions about resources to be allocated to the segment and assess its performance, and for which discrete financial information is available. The Company determines and discloses its segments in accordance with the Financial Accounting Standards Board’s (“FASB”) Accounting Standards Codification Section 280, Segment Reporting, which defines how to determine segments. The Company reports its financial and operating performance in two reportable 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. 

Cash and Cash Equivalents – The Company considers all highly-liquid investments with an original maturity of three months or less to be cash equivalents. The Company maintains its accounts at several financial institutions. These cash balances regularly exceed amounts insured by the Federal Deposit Insurance Corporation, however, the Company does not believe it is exposed to any significant credit risk on these balances. 

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. Due to a limited number of ethanol customers, the Company had significant concentrations of credit risk from sales of ethanol as of December 31, 2017 and 2016, as described below. 

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 $64,501,000 and $64,853,000 at December 31, 2017 and 2016, respectively, were used as collateral under Kinergy’s operating line of credit. The allowance for doubtful accounts was $19,000 and $331,000 as of December 31, 2017 and 2016, respectively. The Company recorded a bad debt expense of $5,000 and $306,000 and a recovery of $354,000 for the years ended December 31, 2017, 2016 and 2015, respectively. The Company does not have any off-balance sheet credit exposure related to its customers.  

Concentration Risks – Credit risk represents the accounting loss that would be recognized at the reporting date if counterparties failed completely to perform as contracted. Concentrations of credit risk, whether on- or off-balance sheet, that arise from financial instruments exist for groups of customers or counterparties when they have similar economic characteristics that would cause their ability to meet contractual obligations to be similarly affected by changes in economic or other conditions described below. Financial instruments that subject the Company to credit risk consist of cash balances maintained in excess of federal depository insurance limits and accounts receivable which have no collateral or security. The Company has not experienced any significant losses in such accounts and believes that it is not exposed to any significant risk of loss of cash. 

The Company sells fuel-grade ethanol to gasoline refining and distribution companies. The Company sold ethanol to customers representing 10% or more of the Company’s total net sales, as follows. 

	Years Ended December 31,
	2017			2016			2015
Customer A		16	%		17	%		12	%
Customer B		11	%		12	%		15	%
Customer C		6	%		6	%		12	%

The Company had accounts receivable due from these customers totaling $21,584,000 and $21,274,000, representing 27% and 25% of total accounts receivable, as of December 31, 2017 and 2016, respectively. 

The Company purchases corn, its largest cost component in producing ethanol, from its suppliers. The Company purchased corn from suppliers representing 10% or more of the Company’s total corn purchases, as follows: 

	Years Ended December 31,
	2017			2016			2015
Supplier A		14	%		13	%		19	%
Supplier B		13	%		4	%		—	%
Supplier C		10	%		8	%		9	%
Supplier D		9	%		13	%		13	%

Approximately 32% of the Company’s employees are covered by a collective bargaining agreement.  

Inventories – Inventories consisted primarily of bulk ethanol, specialty alcohols, corn, co-products, low-carbon and Renewable Identification Number (“RIN”) credits and unleaded fuel, and are valued at the lower-of-cost-or-net realizable value, with cost determined on a first-in, first-out basis. Inventory is net of a $2.7 million valuation adjustment as of December 31, 2017. Inventory balances consisted of the following (in thousands): 

	December 31,
	2017		2016
Finished goods	$	35,652	$	33,773
Work in progress		8,807		7,092
Raw materials		7,601		6,571
Low-carbon and RIN credits		7,952		10,926
Other		1,538		1,708
Total	$	61,550	$	60,070

Property and Equipment – Property and equipment are stated at cost. Depreciation is computed using the straight-line method over the following estimated useful lives: 

Buildings	40 years
Facilities and plant equipment	10 – 25 years
Other equipment, vehicles and furniture	5 – 10 years

 The cost of normal maintenance and repairs is charged to operations as incurred. Significant capital expenditures that increase the life of an asset are capitalized and depreciated over the estimated remaining useful life of the asset. The cost of property and equipment sold, or otherwise disposed of, and the related accumulated depreciation or amortization are removed from the accounts, and any resulting gains or losses are reflected in current operations. 

Intangible Asset – The Company assesses indefinite-lived intangible assets for impairment annually, or more frequently if circumstances indicate impairment may have occurred. If the carrying value of an indefinite-lived intangible asset exceeds its fair value, an impairment loss is recognized in an amount equal to that excess. If the Company determines that an impairment charge is needed, the charge will be recorded as an asset impairment in the consolidated statements of operations. 

Derivative Instruments and Hedging Activities – Derivative transactions, which can include exchange-traded forward contracts and futures positions on the New York Mercantile Exchange or the Chicago Board of Trade, are recorded on the balance sheet as assets and liabilities based on the derivative’s fair value. Changes in the fair value of derivative contracts are recognized currently in income unless specific hedge accounting criteria are met. If derivatives meet those criteria, and hedge accounting is elected, effective gains and losses are deferred in accumulated other comprehensive income (loss) and later recorded together with the hedged item in consolidated income (loss). For derivatives designated as a cash flow hedge, the Company formally documents the hedge and assesses the effectiveness with associated transactions. The Company has designated and documented contracts for the physical delivery of commodity products to and from counterparties as normal purchases and normal sales.

Revenue Recognition – The Company recognizes revenue when it is realized or realizable and earned. The Company considers revenue realized or realizable and earned when there is persuasive evidence of an arrangement, delivery has occurred, the sales price is fixed or determinable, and collection is reasonably assured. The Company derives revenue primarily from sales of ethanol and related co-products. The Company recognizes revenue when title transfers to its customers, which is generally upon the delivery of these products to a customer’s designated location. These deliveries are made in accordance with sales commitments and related sales orders entered into either verbally or in writing with customers. The sales commitments and related sales orders provide quantities, pricing and conditions of sales. In this regard, the Company engages in three basic types of revenue generating transactions:

● As a producer. Sales as a producer consist of sales of the Company’s inventory produced at its plants.

● As a merchant. Sales as a merchant consist of sales to customers through purchases from third-party suppliers in which the Company may or may not obtain physical control of the ethanol, in which shipments are directed from the Company’s suppliers to its terminals or direct to its customers but for which the Company accepts the risk of loss in the transactions.

● As an agent. Sales as an agent consist of sales to customers through purchases from third-party suppliers in which the risks and rewards of inventory ownership remain with third-party suppliers and the Company receives a predetermined service fee under these transactions.

Revenue from sales of third-party ethanol is recorded net of costs when the Company is acting as an agent between a customer and a supplier and gross when the Company is a principal to the transaction. The Company recorded $1,663,000, $1,604,000 and $1,510,000 in net sales when acting as an agent for the years ended December 31, 2017, 2016 and 2015, respectively. Several factors are considered to determine whether the Company is acting as an agent or principal, most notably whether the Company is the primary obligor to the customer and whether the Company has inventory risk and related risk of loss or whether the Company adds meaningful value to the supplier’s product or service. Consideration is also given to whether the Company has latitude in establishing the sales price or has credit risk, or both. When the Company acts as an agent, it recognizes revenue on a net basis or recognizes its predetermined fees and any associated freight, based upon the amount of net revenues retained in excess of amounts paid to suppliers. 

The Company records revenues based upon the gross amounts billed to its customers in transactions where the Company acts as a producer or a merchant and obtains title to ethanol and therefore owns the product and any related, unmitigated inventory risk for the ethanol, regardless of whether the Company actually obtains physical control of the product. 

Shipping and Handling Costs – Shipping and handling costs are classified as a component of cost of goods sold in the accompanying consolidated statements of operations. 

Selling Costs – Selling costs associated with the Company’s product sales are classified as a component of selling, general and administrative expenses in the accompanying consolidated statements of operations. 

Stock-Based Compensation – The Company accounts for the cost of employee services received in exchange for the award of equity instruments based on the fair value of the award, determined on the date of grant. The expense is recognized over the period during which an employee is required to provide services in exchange for the award. The Company accounts for forfeitures as they occur. The Company recognizes stock-based compensation expense as a component of selling, general and administrative expenses in the consolidated statements of operations.

Impairment of Long-Lived Assets – The Company assesses the impairment of long-lived assets, including property and equipment, internally developed software and purchased intangibles subject to amortization, when events or changes in circumstances indicate that the fair value of assets could be less than their net book value. In such event, the Company assesses long-lived assets for impairment by first determining the forecasted, undiscounted cash flows the asset group is expected to generate plus the net proceeds expected from the sale of the asset group. If this amount is less than the carrying value of the asset, the Company will then determine the fair value of the asset group. An impairment loss would be recognized when the fair value is less than the related asset group’s net book value, and an impairment expense would be recorded in the amount of the difference. Forecasts of future cash flows are judgments based on the Company’s experience and knowledge of its operations and the industries in which it operates. These forecasts could be significantly affected by future changes in market conditions, the economic environment, including inflation, and purchasing decisions of the Company’s customers. 

Deferred Financing Costs – Deferred financing costs are costs incurred to obtain debt financing, including all related fees, and are amortized as interest expense over the term of the related financing using the straight-line method, which approximates the interest rate method. Amortization of deferred financing costs was $503,000, $137,000 and $272,000 for the years ended December 31, 2017, 2016 and 2015, respectively. Unamortized deferred financing costs were approximately $1,925,000 and $1,708,000 as of December 31, 2017 and 2016, respectively, and are recorded net of long-term debt in the consolidated balance sheets. 

Provision for Income Taxes – Income taxes are accounted for under the asset and liability approach, where deferred tax assets and liabilities are determined based on differences between financial reporting and tax basis of assets and liabilities, and are measured using enacted tax rates and laws that are expected to be in effect when the differences reverse. Valuation allowances are established when necessary to reduce deferred tax assets to the amounts expected to be realized. 

The Company accounts for uncertainty in income taxes using a two-step approach to recognizing and measuring uncertain tax positions. The first step is to evaluate the tax position for recognition by determining whether it is more likely than not that the position will be sustained on audit, including resolution of related appeals or litigation processes, if any. The second step is to measure the tax benefit as the largest amount which is more than 50% likely of being realized upon ultimate settlement. An uncertain tax position is considered effectively settled on completion of an examination by a taxing authority if certain other conditions are satisfied. Should the Company incur interest and penalties relating to tax uncertainties, such amounts would be classified as a component of interest expense and other income (expense), net, respectively. Deferred tax assets and liabilities are classified as noncurrent in the Company’s consolidated balance sheets. 

The Company files a consolidated federal income tax return. This return includes all wholly-owned subsidiaries as well as the Company’s pro-rata share of taxable income from pass-through entities in which the Company owns less than 100%. State tax returns are filed on a consolidated, combined or separate basis depending on the applicable laws relating to the Company and its subsidiaries. 

Income (Loss) Per Share – Basic income (loss) per share is computed on the basis of the weighted-average number of shares of common stock outstanding during the period. Preferred dividends are deducted from net income (loss) attributed to Pacific Ethanol, Inc. and are considered in the calculation of income (loss) available to common stockholders in computing basic income (loss) per share. Common stock equivalents to the preferred stock are considered participating securities and are also included in this calculation when dilutive.

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

	Year Ended December 31, 2017
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(34,964	)
Less: Preferred stock dividends		(1,265	)
Basic and Diluted loss per share:
Loss available to common stockholders	$	(36,229	)		42,745	$	(0.85	)

	Year Ended December 31, 2016
	Income Numerator			Shares Denominator		Per-Share Amount
Net income attributed to Pacific Ethanol	$	1,419
Less: Preferred stock dividends		(1,269	)
Less: Allocated to participating securities		(2	)
Basic income per share:
Income available to common stockholders	$	148			42,182	$	0.00
Add: Options		—			69
Diluted income per share:
Income available to common stockholders	$	148			42,251	$	0.00

	Year Ended December 31, 2015
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(18,786	)
Less: Preferred stock dividends		(1,265	)
Basic and Diluted loss per share:
Loss available to common stockholders	$	(20,051	)		33,173	$	(0.60	)

There were an aggregate of 719,000, 704,000 and 817,000 potentially dilutive shares from convertible securities outstanding as of December 31, 2017, 2016 and 2015, respectively. These convertible securities were not considered in calculating diluted income (loss) per common share for the years ended December 31, 2017, 2016 and 2015 as their effect would be anti-dilutive.

Financial Instruments – The carrying values of cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities 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.

Employment-related Benefits – Employment-related benefits associated with pensions and postretirement health care are expensed based on actuarial analysis. The recognition of expense is affected by estimates made by management, such as discount rates used to value certain liabilities, investment rates of return on plan assets, increases in future wage amounts and future health care costs. Discount rates are determined based on a spot yield curve that includes bonds with maturities that match expected benefit payments under the plan. 

Estimates and Assumptions – The preparation of the consolidated financial statements in conformity with GAAP 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 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.

Subsequent Events – Management evaluates, as of each reporting period, events or transactions that occur after the balance sheet date through the date that the financial statements are issued for either disclosure or adjustment to the consolidated financial results.

Reclassifications – Certain prior year amounts have been reclassified to conform to the current presentation, including the classification of cash collateral balances held with commodity brokers and the classification of external selling costs with respect to the Company’s co-product sales. Cash collateral balances of $4,331,000 as of December 31, 2016 were reclassified from cash and cash equivalents to other current assets on the consolidated balance sheet. External selling costs for the years ended December 31, 2016 and 2015 of $2,526,000 and $2,956,000, respectively, were reclassified from cost of goods sold to selling, general and administrative expenses on the consolidated statements of operations. Such reclassifications had no effect on the consolidated net income (loss), working capital or stockholder’s equity reported in the consolidated statements of operations and consolidated balance sheets.

Recent Accounting Pronouncements – In May 2014, the FASB issued new guidance on the recognition of revenue (“ASC 606”). 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 adopted ASC 606 on January 1, 2018. The Company has completed its evaluation of the new requirements under ASC 606 on each of its major revenue types. The Company’s 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, however, will expand certain disclosures of its revenue streams. The Company will adopt the new guidance using the modified retrospective transition method.

In February 2016, the 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, 2018, including interim periods within those fiscal years. The Company expects that upon adoption of this accounting standard, right of use assets and lease obligations will be recognized in its consolidated balance sheets in amounts that will be material.

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.

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PACIFIC ETHANOL PLANTS.

12 Months Ended

Dec. 31, 2017

Business Combinations [Abstract]

PACIFIC ETHANOL PLANTS.

2. PACIFIC ETHANOL PLANTS.

Illinois Corn Processing

On July 3, 2017, the Company purchased 100% of the equity interests of ICP from ICP’s owners, Illinois Corn Processing Holdings Inc. (“ICPH”) and MGPI Processing, Inc. (together with ICPH, the “Sellers”). At the closing, ICP became an indirect wholly-owned subsidiary of the Company.

Upon closing, the Company (i) paid to the Sellers $30.0 million in cash, and (ii) issued to the Sellers secured promissory notes in the aggregate principal amount of approximately $46.9 million (the “Seller Notes”). The Seller Notes were secured by a first priority lien on ICP’s assets 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 Company’s facility in Pekin, Illinois and is located on the Illinois River. ICP produces fuel-grade ethanol, beverage and industrial-grade alcohol, dry distillers grain and corn oil. The facility has direct access to end-markets via barge, rail and truck, and expands the Company’s domestic and international distribution channels. ICP is reflected in the results of the Company’s production segment.

The Company has recognized the following allocation of the purchase price at fair values. No intangible assets or liabilities have been recognized due to ICP’s contracts being materially close to market prices. The Company’s purchase price consideration allocation is as follows (in thousands):

Cash and equivalents	$	426
Accounts receivable		11,636
Inventories		9,227
Other current assets		1,560
Total current assets		22,849
Property and equipment		61,128
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. 

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

	Years Ended December 31,
	2017			2016
Revenues – pro forma	$	1,710,317		$	1,802,159
Consolidated net income (loss) – pro forma	$	(42,589	)	$	8,329
Diluted net income (loss) per share – pro forma	$	(0.95	)	$	0.16
Diluted weighted-average shares – pro forma		42,745			42,251

For the year ended December 31, 2017, ICP contributed $75.9 million in net revenues and $3.7 million in pre-tax income. For the year ended December 31, 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.

 PE Central 

On July 1, 2015, the Company acquired 100% of PE Central and its plants, through a stock-for-stock merger. The Company issued an aggregate of 17.8 million shares of common stock and non-voting common stock for 100% of the outstanding shares of common stock of PE Central. The common stock and non-voting common stock issued as consideration had an aggregate fair value of $174.6 million, based on the closing market price of the Company’s common stock on the acquisition date. 

The Company believes the acquisition of PE Central resulted in a number of synergies and strategic advantages. The Company believes the acquisition spread commodity and basis price risks across diverse markets and products, assisting in its efforts to optimize margin management; improved its hedging opportunities with a greater correlation to the liquid physical and paper markets in Chicago; and increased its flexibility and alternatives in feedstock procurement for its Midwestern and Western production facilities. The acquisition also expanded the Company’s marketing reach into new markets and extended its mix of co-products. The Company believes the acquisition enabled it to have deeper market insight and engagement in major ethanol and feed markets outside the Western United States, thereby improving pricing opportunities; allowed the Company to establish access to markets in 48 states for ethanol sales and access many markets with ethanol and co-product sales reaching domestic and international customers; and enabled it to use its more diverse mix of co-products to generate strong co-product returns. 

The Company recognized the following allocation of the purchase price at fair values. The Company included in the following allocation its estimated fair values for certain operating lease agreements and open commitments. The fair-value determination of long-term debt was based on the interest rate environment at the acquisition date. Based on the final allocation, the Company recorded an immaterial bargain purchase gain on the acquisition. 

The purchase price consideration allocation is as follows (in thousands):

Cash and equivalents	$	18,756
Accounts receivable		10,430
Inventories		29,483
Other current assets		8,304
Total current assets		66,973
Property and equipment		312,781
Net deferred tax assets		12,159
Other assets		750
Total assets acquired	$	392,663
Accounts payable and accrued liabilities	$	27,780
Long-term debt - revolvers		13,721
Long-term debt - term debt		142,744
Pension plan liabilities		8,518
Other non-current liabilities		25,327
Total liabilities assumed	$	218,090
Net assets acquired	$	174,573

The contractual amount due on the accounts receivable acquired was $10.8 million, of which $0.4 million is expected to be uncollectible. In accounting for the acquisition, the Company recorded $3.7 million in other noncurrent liabilities as a litigation contingency related to certain litigation matters for amounts that were probable and estimable as of the acquisition date. Subsequent to the acquisition date, the Company settled for $2.1 million certain litigation for which liabilities were recorded. Certain of these settlements were made after the measurement period, and as such the Company recorded a gain of $1.1 million for the year ended December 31, 2016 in selling, general and administrative expenses in the accompanying consolidated statements of operations. See Note 14 for further details. 

The following table presents unaudited pro forma financial information for the year ended December 31, 2015, assuming the acquisition occurred on January 1, 2014 (in thousands except per share data). 

Net sales – pro forma	$	1,484,676
Cost of goods sold – pro forma	$	1,469,512
Selling, general and administrative expenses – pro forma	$	34,735
Net loss – pro forma	$	(34,136	)
Diluted net loss per share – pro forma	$	(0.81	)
Diluted weighted-average shares – pro forma		42,053

The effects of the initial step-up of inventories and open contracts in the aggregate of $8.7 million recorded during 2015 were excluded in the above amounts for 2015 as if the acquisition had occurred on January 1, 2014. For the six months ended December 31, 2015, PE Central contributed $299.0 million in net sales and $16.3 million in pre-tax loss. For the year ended December 31, 2017, PE Central contributed $610.5 million in net sales and $8.4 million in pre-tax loss. For the year ended December 31, 2016, PE Central contributed $650.1 million in net sales and $2.1 million in pre-tax income. For the year ended December 31, 2015, the Company recorded approximately $1.4 million in costs associated with the PE Central acquisition. These costs are reflected in selling, general and administrative expenses on the Company’s consolidated statements of operations, but were excluded from the amounts above. 

Pacific Aurora  

On December 15, 2016, PE Central closed on an agreement with ACEC under which (i) PE Central contributed to Pacific Aurora 100% of the equity interests of its wholly-owned subsidiaries, Pacific Ethanol Aurora East, LLC (“AE”) and Pacific Ethanol Aurora West, LLC (“AW”), which owned the Company’s Aurora East and Aurora West ethanol plants, respectively, in exchange for an 88.15% ownership interest in Pacific Aurora, and (ii) ACEC contributed to Pacific Aurora its grain elevator adjacent to the Aurora East and Aurora West properties and related grain handling assets, including the outer rail loop and the real property on which they are located, in exchange for an 11.85% ownership interest in Pacific Aurora. On December 15, 2016, concurrent with the closing of the contribution transaction, PE Central sold a 14.22% ownership interest in Pacific Aurora to ACEC for $30.0 million in cash. 

Following the closing of these transactions, PE Central owned 73.93% of Pacific Aurora and ACEC owned 26.07% of Pacific Aurora. 

The Company has consolidated 100% of the results of Pacific Aurora and recorded the amount attributed to ACEC as noncontrolling interests under the voting rights model. Since the Company had control of AE and AW prior to forming Pacific Aurora, there was no gain or loss recorded on the contribution and ultimate sale of a portion of the Company’s interests in Pacific Aurora. ACEC contributed $16.5 million in assets at fair market value and paid $30.0 million in cash for its additional ownership interests. A noncontrolling interest was recognized to reflect ACEC’s proportional ownership interest multiplied by the book value of Pacific Aurora’s net assets. As a result, the Company recorded $16.2 million as additional paid-in capital attributed to the difference between Pacific Aurora’s book value and the contribution and sale. 

On December 15, 2016, the Company entered into a working capital maintenance agreement with Pacific Aurora’s lender, under which the Company agreed to contribute capital to Pacific Aurora from time to time, if needed, in an amount up to $15.0 million to ensure that Pacific Aurora maintains the minimum working capital thresholds required in its credit agreement as further discussed in Note 9. In addition, dividends from Pacific Aurora to its members are limited to 40% of Pacific Aurora’s annual net income. 

The carrying values and classification of assets and liabilities of Pacific Aurora as of December 31, 2016 were as follows (in thousands): 

Cash and equivalents	$	1,453
Accounts receivable		16,804
Inventories		3,837
Other current assets		77
Total current assets		22,171
Property and equipment		115,759
Other assets		1,387
Total assets	$	139,317
Accounts payable and accrued liabilities	$	20,152
Other current liabilities		2,045
Long-term debt outstanding, net		621
Total liabilities	$	22,818

 PE OP Co.

Prior to May 2015, the Company held a 96% ownership in PE Op Co. In May 2015, it purchased the remaining 4% ownership interest in PE Op Co. for $6.0 million in cash, bringing its ownership of PE Op Co. to 100%. 

Because the Company had a controlling financial interest in PE Op Co. at the time of this purchase, it did not record any gains or losses, but instead reduced the amount of noncontrolling interest on the consolidated balance sheets by an aggregate of $4.4 million and recorded the difference of $0.6 million and for the year ended December 31, 2015, which represented the fair value of this purchase above the price paid by the Company, to additional paid-in capital on the consolidated balance sheet.

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INTERCOMPANY AGREEMENTS.

12 Months Ended

Dec. 31, 2017

Intercompany Agreements

INTERCOMPANY AGREEMENTS.

3. INTERCOMPANY AGREEMENTS.

The Company, directly or through one of its subsidiaries, has entered into the following management and marketing agreements:

Affiliate Management Agreement – Pacific Ethanol entered into an Affiliate Management Agreement (“AMA”) with its operating subsidiaries, namely Kinergy, PAP, the Pacific Ethanol West Plants and the Pacific Ethanol Central Plants, effective July 1, 2015, with Pacific Aurora, effective December 15, 2016, and with ICP, effective July 1, 2017, under which Pacific Ethanol agreed to provide operational and administrative and staff support services. These services generally include, but are not limited to, administering the subsidiaries’ compliance with their credit agreements and performing billing, collection, record keeping and other administrative and ministerial tasks. Pacific Ethanol agreed to supply all labor and personnel required to perform its services under the AMA, including the labor and personnel required to operate and maintain the production facilities and marketing activities. These services are billed at a predetermined amount per subsidiary each month plus out of pocket costs such as employee wages and benefits.

The AMAs have an initial term of one year and automatic successive one year renewal periods. Pacific Ethanol may terminate the AMA, and any subsidiary may terminate the AMA, at any time by providing at least 90 days prior notice of such termination.

Pacific Ethanol recorded revenues of approximately $11,904,000, $12,968,000 and $9,857,000 related to the AMAs in place for the years ended December 31, 2017, 2016 and 2015, respectively. These amounts have been eliminated upon consolidation.

Ethanol Marketing Agreements – Kinergy entered into separate ethanol marketing agreements with each of the Company’s nine plants, which granted it the exclusive right to purchase, market and sell the ethanol produced at those facilities. Under the terms of the ethanol marketing agreements, within ten days after delivering ethanol to Kinergy, an amount is paid to Kinergy equal to (i) the estimated purchase price payable by the third-party purchaser of the ethanol, minus (ii) the estimated amount of transportation costs to be incurred, minus (iii) the estimated incentive fee payable to Kinergy, which equals 1% of the aggregate third-party purchase price, provided that the marketing fee shall not be less than $0.015 per gallon and not more than $0.0225 per gallon. Each of the ethanol marketing agreements had an initial term of one year and successive one year renewal periods at the option of the individual plant.

Kinergy recorded revenues of approximately $8,464,000, $8,029,000 and $5,262,000 related to the ethanol marketing agreements for the years ended December 31, 2017, 2016 and 2015, respectively. These amounts have been eliminated upon consolidation.

Corn Procurement and Handling Agreements – PAP entered into separate corn procurement and handling agreements with each of the Company’s plants, with the exception of the Pacific Aurora facilities, which terminated its agreements with PAP on December 15, 2016. Under the terms of the corn procurement and handling agreements, each facility appointed PAP as its exclusive agent to solicit, negotiate, enter into and administer, on its behalf, corn supply arrangements to procure the corn necessary to operate its facility. PAP also provides grain handling services including, but not limited to, receiving, unloading and conveying corn into the facility’s storage and, in the case of whole corn delivered, processing and hammering the whole corn.

Under these agreements, PAP receives a fee of $0.045 per bushel of corn delivered to each facility as consideration for its procurement and handling services, payable monthly. Effective December 15, 2016, this fee is $0.03 per bushel of corn. Each corn procurement and handling agreement had an initial term of one year and successive one year renewal periods at the option of the individual plant. PAP recorded revenues of approximately $4,245,000, $4,386,000 and $2,910,000 related to the corn procurement and handling agreements for the years ended December 31, 2017, 2016 and 2015, respectively. These amounts have been eliminated upon consolidation.

Effective December 15, 2016, each Pacific Aurora facility entered into a new grain procurement agreement with ACEC. Under this agreement, ACEC receives a fee of $0.03 per bushel of corn delivered to each facility as consideration for its procurement and handling services, payable monthly. The grain procurement agreement has an initial term of one year and successive one year renewal periods at the option of the individual plant. Pacific Aurora recorded expenses of approximately $816,000 and $107,000 for the year ended December 31, 2017 and the period from December 15, 2016 to December 31, 2016, respectively. These amounts have not been eliminated upon consolidation as they are with a related but unconsolidated third-party.

Distillers Grains Marketing Agreements – PAP entered into separate distillers grains marketing agreements with each of the Company’s plants, which grant PAP the exclusive right to market, purchase and sell the various co-products produced at each facility. Under the terms of the distillers grains marketing agreements, within ten days after a plant delivers co-products to PAP, the plant is paid an amount equal to (i) the estimated purchase price payable by the third-party purchaser of the co-products, minus (ii) the estimated amount of transportation costs to be incurred, minus (iii) the estimated amount of fees and taxes payable to governmental authorities in connection with the tonnage of the co-products produced or marketed, minus (iv) the estimated incentive fee payable to the Company, which equals (a) 5% of the aggregate third-party purchase price for wet corn gluten feed, wet distillers grains, corn condensed distillers solubles and distillers grains with solubles, or (b) 1% of the aggregate third-party purchase price for corn gluten meal, dry corn gluten feed, dry distillers grains, corn germ and corn oil. Each distillers grains marketing agreement had an initial term of one year and successive one year renewal periods at the option of the individual plant.

PAP recorded revenues of approximately $6,020,000, $6,047,000 and $4,438,000 related to the distillers grains marketing agreements for the years ended December 31, 2017, 2016 and 2015, respectively. These amounts have been eliminated upon consolidation.

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SEGMENTS.

12 Months Ended

Dec. 31, 2017

Segment Reporting [Abstract]

SEGMENTS.

4. 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.

Income before provision for income taxes includes management fees charged by Pacific Ethanol to the segment. The production segment incurred $9,744,000, $9,968,000 and $5,957,000 in management fees for the years ended December 31, 2017, 2016 and 2015, respectively. The marketing and distribution segment incurred $2,160,000, $3,000,000 and $3,900,000 in management fees for the years ended December 31, 2017, 2016 and 2015, respectively. Corporate activities include selling, general and administrative expenses, consisting primarily of corporate employee compensation, professional fees and overhead costs not directly related to a specific operating segment.

During the normal course of business, the segments do business with each other. The preponderance of this activity occurs when the Company’s marketing segment markets ethanol produced by the production segment for a marketing fee, as discussed in Note 3. These intersegment activities are considered arms’-length transactions. Consequently, although these transactions impact segment performance, they do not impact the Company’s consolidated results since all revenues and corresponding costs are eliminated in consolidation.

Capital expenditures are substantially all incurred at the Company’s production segment.

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

	Years Ended December 31,
	2017			2016			2015
Net Sales
Production:
Net sales to external customers	$	1,102,722		$	1,045,807		$	710,201
Intersegment net sales		1,898			1,169			—
Total production segment net sales		1,104,620			1,046,976			710,201
Marketing and distribution:
Net sales to external customers		529,533			578,951			480,975
Intersegment net sales		8,464			8,029			5,262
Total marketing and distribution net sales		537,997			586,980			486,237
Intersegment eliminations		(10,362	)		(9,198	)		(5,262	)
Net sales as reported	$	1,632,255		$	1,624,758		$	1,191,176
Cost of goods sold:
Production	$	1,098,977		$	1,015,655		$	716,877
Marketing and distribution		535,032			575,921			476,410
Intersegment eliminations		(7,685	)		(21,176	)		(12,477	)
Cost of goods sold as reported	$	1,626,324		$	1,570,400		$	1,180,810
Income (loss) before provision for income taxes:
Production	$	(27,458	)	$	(6,882	)	$	(32,723	)
Marketing and distribution		(2,463	)		4,517			3,200
Corporate activities		(8,474	)		2,910			616
	$	(38,395	)	$	545		$	(28,907	)
Depreciation and amortization:
Production	$	37,637		$	34,528		$	23,091
Marketing and distribution		—			3			151
Corporate activities		1,014			910			390
	$	38,651		$	35,441		$	23,632
Interest expense:
Production	$	5,887		$	20,794		$	11,969
Marketing and distribution		1,271			1,404			625
Corporate activities		5,780			208			—
	$	12,938		$	22,406		$	12,594

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

	December 31,
	2017		2016
Total assets:
Production	$	583,696	$	542,688
Marketing and distribution		127,242		146,356
Corporate assets		9,358		19,194
	$	720,296	$	708,238

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PROPERTY AND EQUIPMENT.

12 Months Ended

Dec. 31, 2017

Property, Plant and Equipment [Abstract]

PROPERTY AND EQUIPMENT.

5. PROPERTY AND EQUIPMENT.

Property and equipment consisted of the following (in thousands):

	December 31,
	2017			2016
Facilities and plant equipment	$	601,156		$	530,735
Land		8,970			7,771
Other equipment, vehicles and furniture		10,189			9,714
Construction in progress		38,041			29,393
		658,356			577,613
Accumulated depreciation		(150,004	)		(112,423	)
	$	508,352		$	465,190

Depreciation expense was $38,651,000, $35,441,000 and $23,632,000 for the years ended December 31, 2017, 2016 and 2015, respectively. For the year ended December 31, 2015, the Company recorded an impairment charge of $1,970,000 related to the abandonment of certain accounting and information technology systems following the integration of its PE Central facilities.

For the year ended December 31, 2017 and 2016, the Company capitalized interest of $822,000 and $1,307,000, respectively, related to its capital investment activities.

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INTANGIBLE ASSETS.

12 Months Ended

Dec. 31, 2017

Goodwill and Intangible Assets Disclosure [Abstract]

INTANGIBLE ASSETS.

6. INTANGIBLE ASSET.

The Company recorded a tradename valued at $2,678,000 in 2006 as part of its acquisition of Kinergy. The Company determined that the Kinergy tradename has an indefinite life and, therefore, rather than being amortized, will be tested annually for impairment. The Company did not record any impairment of the Kinergy tradename for the years ended December 31, 2017, 2016 and 2015.

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DERIVATIVES.

12 Months Ended

Dec. 31, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVES.

7. 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 in order 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 years ended December 31, 2017, 2016 and 2015, 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 net losses of $2,077,000, $1,984,000 and $542,000 as the change in the fair value of these contracts for the years ended December 31, 2017, 2016 and 2015, respectively. 

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

	As of December 31, 2017
	Assets			Liabilities
Type of Instrument	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Cash collateral balance	Other current assets	$	3,813
Commodity contracts	Derivative assets	$	998	Derivative liabilities	$	2,307

	As of December 31, 2016
	Assets			Liabilities
Type of Instrument	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Cash collateral balance	Other current assets	$	4,331
Commodity contracts	Derivative assets	$	978	Derivative liabilities	$	4,115

The above amounts represent the gross balances of the contracts, however, the Company does have the right of offset with each of its derivative brokers.

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)
		For the Years Ended December 31,
Type of Instrument	Statements of Operations Location	2017			2016		2015
Commodity contracts	Cost of goods sold	$	(4,165	)	$	1,386	$	(338	)
		$	(4,165	)	$	1,386	$	(338	)

		Unrealized Gains (Losses)
		For the Years Ended December 31,
Type of Instrument	Statements of Operations Location	2017		2016			2015
Commodity contracts	Cost of goods sold	$	2,088	$	(3,370	)	$	(204	)
		$	2,088	$	(3,370	)	$	(204	)

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DEBT.

12 Months Ended

Dec. 31, 2017

Debt Disclosure [Abstract]

DEBT.

8. DEBT.

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

	December 31, 2017			December 31, 2016
Kinergy line of credit	$	49,477		$	49,862
Pekin term loan		53,500			64,000
Pekin revolving loan		32,000			32,000
ICP term loan		22,500			—
ICP revolving loan		18,000			—
Pacific Aurora line of credit		—			1,000
Parent notes payable		68,948			55,000
		244,425			201,862
Less unamortized debt discount		(1,409	)		(1,626	)
Less unamortized debt financing costs		(1,925	)		(1,708	)
Less short-term portion		(20,000	)		(10,500	)
Long-term debt	$	221,091		$	188,028

 Kinergy Line of Credit – Kinergy has an operating line of credit for an aggregate amount of up to $100,000,000. The line of credit matures on August 2, 2022. The credit facility is based on Kinergy’s eligible accounts receivable and inventory levels, subject to certain concentration reserves. The credit facility is subject to certain other sublimits, including inventory loan limits. Interest accrues under the line of credit at a rate equal to (i) the three-month London Interbank Offered Rate (“LIBOR”), plus (ii) a specified applicable margin ranging between 1.50% and 2.00%. The applicable margin was 1.75%, for a total rate of 3.44% at December 31, 2017. The credit facility’s monthly unused line fee is an annual rate equal to 0.25% to 0.375% depending on the average daily principal balance during the immediately preceding month. Payments that may be made by Kinergy to the Company as reimbursement for management and other services provided by the Company to Kinergy are limited under the terms of the credit facility to $1,500,000 per fiscal quarter. 

The credit facility also includes the accounts receivable of PAP as additional collateral. Payments that may be made by PAP to the Company as reimbursement for management and other services provided by the Company to PAP are limited under the terms of the credit facility to $500,000 per fiscal quarter. 

If Kinergy and PAP’s monthly excess borrowing availability falls below certain thresholds, they are collectively required to maintain a fixed-charge coverage ratio (calculated as a twelve-month rolling EBITDA divided by the sum of interest expense, capital expenditures, 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 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. Pacific Ethanol has guaranteed all of Kinergy’s obligations under the line of credit. As of December 31, 2017, Kinergy had an available unused availability under the credit facility of $27,399,000. 

Pekin Credit Facilities – On December 15, 2016, the Company’s wholly-owned subsidiary, Pacific Ethanol Pekin, Inc. (“Pekin”), entered into a Credit Agreement (the “Pekin Credit Agreement”) with 1^st Farm Credit Services, PCA and CoBank, ACB (“CoBank”). On December 15, 2016, under the terms of the Pekin Credit Agreement, Pekin borrowed from 1^st Farm Credit Services $64.0 million under a term loan facility that matures on August 20, 2021 (the “Pekin Term Loan”) and $32.0 million under a revolving term loan facility that matures on February 1, 2022 (the “Pekin Revolving Loan” and, together with the Pekin Term Loan, the “Pekin Credit Facility”). The Pekin Credit Facility is secured by a first-priority security interest in all of Pekin’s assets under the terms of a Security Agreement, dated December 15, 2016, by and between Pekin and CoBank (the “Pekin Security Agreement”). Interest accrues under the Pekin Credit Facility at an annual rate equal to the 30-day LIBOR plus 3.75%, payable monthly. Pekin is required to make quarterly principal payments in the amount of $3.5 million on the Pekin Term Loan beginning on May 20, 2017 and a principal payment of $4.5 million at maturity on August 20, 2021. Pekin is required to pay a monthly fee on any unused portion of the Pekin Revolving Loan at a rate of 0.75% per annum. Prepayment of the Pekin Credit Facility is subject to a prepayment penalty. Under the terms of the Pekin Credit Agreement, Pekin is required to maintain not less than $20.0 million in working capital and an annual debt coverage ratio of not less than 1.25 to 1.0. The Pekin Credit Agreement contains a variety of affirmative covenants, negative covenants and events of default. 

On August 7, 2017, 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%. Pekin and its lender also agreed that 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. For the month ended January 31, 2018, Pekin was not in compliance with its working capital requirement due to larger than anticipated repair and maintenance related expenses to replace faulty equipment. Pekin has received a waiver from its lender for this noncompliance. Further, the lender decreased Pekin’s working capital covenant requirement to be $13.0 million for the month ended February 28, 2018, excluding the $3.5 million principal payment due in May 2018 from the calculation. As of the filing of this report, management believes Pekin is in compliance with its working capital requirement. 

ICP Credit Facilities — On September 15, 2017, ICP, Compeer Financial, PCA (“Compeer”), and CoBank as agent, entered into a Credit Agreement (“ICP Credit Agreement”). Under the ICP Credit Agreement, Compeer 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. ICP used the proceeds of the term 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. ICP used 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 CoBank ten days prior written notice. The revolving loan requires ICP to pay CoBank 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 service coverage ratio of not less than 1.50 to 1.00 beginning for the year ending December 31, 2018. 

Pacific Aurora Line of Credit – On December 15, 2016, Pacific Aurora entered into a credit agreement (the “Pacific Aurora Credit Agreement”) with CoBank. Under the terms of the Pacific Aurora Credit Agreement, Pacific Aurora may borrow up to $30.0 million under a revolving term loan facility from CoBank that matures on February 1, 2022 (the “Pacific Aurora Credit Facility”). The Pacific Aurora Credit Facility is secured by a first-priority security interest in all of Pacific Aurora’s assets under the terms of a Security Agreement, dated December 15, 2016, by and among Pacific Aurora and CoBank (the “Pacific Aurora Security Agreement”). Borrowing availability under the Pacific Aurora Credit Facility automatically declines by $2.5 million on the first day of each June and December beginning on June 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 Pacific Aurora Credit Facility at a rate of 0.75% per annum. Prepayment of the Pacific Aurora Credit Facility is subject to a prepayment penalty. Under the terms of the Pacific Aurora Credit Agreement, Pacific Aurora was required to maintain not less than $22.5 million in working capital through June 30, 2017, not less than $24.0 million in working capital after June 30, 2017, and an annual debt service coverage ratio of not less than 1.50 to 1.00. These covenants were partially amended, as noted below. 

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. 

At December 31, 2017, Pacific Aurora was not in compliance with its working capital and Debt Service Coverage Ratio requirements. The Company did not utilize the credit facility in 2017 and has no plans to draw on the facility at this time, having addressed the liquidity and capital needs of Pacific Aurora through other means. Consequently, the Company is in discussions with its lender to either amend the credit facility or terminate it.

Pacific Ethanol, Inc. Notes Payable – On December 12, 2016, Pacific Ethanol entered into a Note Purchase Agreement (the “Note Purchase Agreement”) with five accredited investors. On December 15, 2016, under the terms of the Note Purchase Agreement, Pacific Ethanol sold $55.0 million in aggregate principal amount of its senior secured notes to the Investors in a private offering for aggregate gross proceeds of 97% of the principal amount of the Notes sold. On June 26, 2017, the Company entered into a second Note Purchase Agreement with five accredited investors. On June 30, 2017, under the terms of the second Note Purchase Agreement, the Company sold an additional $13.9 million in aggregate principal amount of its senior secured notes to the investors in a private offering for aggregate gross proceeds of 97% of the principal amount of the notes sold (collectively with the notes sold on December 15, 2016, the “Notes”), for a total of $68.9 million in aggregate principal amount of Notes.

The Notes mature on December 15, 2019 (the “Maturity Date”). Interest on the Notes accrues at a rate equal to (i) the greater of 1% and the three-month LIBOR, plus 7.0% from the closing 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. The interest rate increases by an additional 2% per annum above the interest rate otherwise applicable upon the occurrence and during the continuance of an event of default until such event of default has been cured. Interest is payable in cash on the 15th calendar day of each March, June, September and December. Pacific Ethanol is required to pay all outstanding principal and any accrued and unpaid interest on the Notes on the Maturity Date. Pacific Ethanol may, at its option, prepay the outstanding principal amount of the Notes at any time without premium or penalty. The Notes contain a variety of events of default. The payments due under the Notes rank senior to all other indebtedness of Pacific Ethanol, other than permitted senior indebtedness. The Notes contain a variety of obligations on the part of Pacific Ethanol not to engage in certain activities, including that (i) Pacific Ethanol and certain of its subsidiaries will not incur other indebtedness, except for certain permitted indebtedness, (ii) Pacific Ethanol and certain of its subsidiaries will not redeem, repurchase or pay any dividend or distribution on their respective capital stock without the prior consent of the holders of the Notes holding 66-2/3% of the aggregate principal amount of the Notes, other than certain permitted distributions, (iii) Pacific Ethanol and certain of its subsidiaries will not sell, lease, assign, transfer or otherwise dispose of any assets of Pacific Ethanol or any such subsidiary, except for certain permitted dispositions (including the sales of inventory or receivables in the ordinary course of business), and (iv) Pacific Ethanol and certain of its subsidiaries will not issue any capital stock or membership interests for any purpose other than to pay down a portion of all of the amounts owed under the Notes and in connection with Pacific Ethanol’s stock incentive plans. The Notes are secured by a first-priority security interest in the equity interest held by Pacific Ethanol in its wholly-owned subsidiary, PE Op. Co., which indirectly owns the Company’s plants located on the West Coast. 

Pacific Ethanol West Plants’ Term Debt – The Pacific Ethanol West Plants’ debt as of December 31, 2015 consisted of a $17,003,000 tranche A-1 term loan which was to mature in June 2016. On February 26, 2016, the Company retired the $17,003,000 outstanding balance by purchasing the lender’s position for cash at par without any prepayment penalty. The purchase increased the amount of the term debt held by Pacific Ethanol from $41,763,000 at December 31, 2015 to $58,766,000 at December 31, 2016 and 2017, which is eliminated upon consolidation, as the Company has no continuing obligations to any third-party lender under the credit agreements associated with this term debt. 

Pacific Ethanol Central Plants’ Term Debt – On July 1, 2015, upon effectiveness of the PE Central acquisition, PE Central became a wholly-owned subsidiary of the Company and, on a consolidated basis, the combined company became obligated with respect to the Pacific Ethanol Central Plants’ term loan and revolving credit facilities. In connection with the Company’s allocation of purchase price, the debt was recorded at $142,744,000, net of a discount of $2,875,000. The term loan facility was to mature on September 24, 2017. The term loan facility was secured through a first-priority lien on substantially all of the Pacific Ethanol Central Plants’ assets. 

Interest on the term loan facility accrued and could either be paid in cash at a rate of 10.5% per annum or paid in-kind at a rate of 15.0% per annum by adding such interest to the outstanding principal balance. The Company paid interest in cash for the period from July 1, 2015, the effective date of the PE Central acquisition, through December 31, 2015. During the year ended December 31, 2016, the Company elected to pay in-kind an aggregate of $9,451,000 of interest, which was added to the principal balance. As of December 15, 2016, the principal balance was $155,070,205. On December 15, 2016, the Company paid in full the outstanding principal balance and all accrued and unpaid interest. The Company did not pay any prepayment penalties. The Company fully amortized the remaining unamortized debt discount of $1,152,000 and recorded the amount in interest expense for the year ended December 31, 2016. 

Maturities of Long-term Debt – The Company’s long-term debt matures as follows (in thousands):  

December 31:
	2018	$	20,000
	2019		88,948
	2020		20,000
	2021		16,000
	2022		99,477
		$	244,425

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PENSION PLANS.

12 Months Ended

Dec. 31, 2017

Retirement Benefits [Abstract]

PENSION PLANS.

9. PENSION PLANS.

Retirement Plan - The Company sponsors a defined benefit pension plan (the “Retirement Plan”) that is noncontributory, and covers only “grandfathered” unionized employees at its Pekin, Illinois, facility. The Company assumed the Retirement Plan as part of its acquisition of PE Central on July 1, 2015. Benefits are based on a prescribed formula based upon the employee’s years of service. Employees hired after November 1, 2010, are not eligible to participate in the Retirement Plan. The Company uses a December 31 measurement date for its Retirement Plan. The Company’s funding policy is to make the minimum annual contribution required by applicable regulations.

Information related to the Retirement Plan as of and for the years ended December 31, 2017, 2016 and 2015 is presented below (dollars in thousands):

	2017			2016			2015
Changes in plan assets:
Fair value of plan assets, beginning	$	12,423		$	12,567		$	13,180
Actual gains (losses)		1,722			523			(298	)
Benefits paid		(665	)		(667	)		(315	)
Company contributions		478			—			—
Participant contributions		—			—			—
Fair value of plan assets, ending	$	13,958		$	12,423		$	12,567
Less: projected accumulated benefit obligation	$	19,658		$	18,455		$	16,552
Funded status, (underfunded)/overfunded	$	(5,700	)	$	(6,032	)	$	(3,985	)
Amounts recognized in the consolidated balance sheets:
Other liabilities	$	(5,700	)	$	(6,032	)	$	(3,985	)
Accumulated other comprehensive loss (income)	$	726		$	1,047		$	(885	)
Components of net periodic benefit costs are as follows:
Service cost	$	391		$	223		$	211
Interest cost		750			686			338
Expected return on plan assets		(674	)		(794	)		(500	)
Net periodic benefit cost	$	467		$	115		$	49
Loss (gain) recognized in other comprehensive income (expense)	$	(321	)	$	1,932		$	(885	)
Assumptions used in computation benefit obligations:
Discount rate		3.60	%		4.15	%		4.23	%
Expected long-term return on plan assets		6.00	%		6.75	%		7.75	%
Rate of compensation increase		—			—			—

The Company expects to make contributions in the year ending December 31, 2018 of approximately $1.0 million. Net periodic benefit cost for 2018 is estimated at approximately $0.3 million.

The following table summarizes the expected benefit payments for the Company’s plan for each of the next five fiscal years and in the aggregate for the five fiscal years thereafter (in thousands):

December 31:
	2018	$	730
	2019		740
	2020		780
	2021		790
	2022		830
	2023-27		4,820
		$	8,690

See Note 15 for discussion of the plan’s fair value disclosures.

Historical and future expected returns of multiple asset classes were analyzed to develop a risk-free real rate of return and risk premiums for each asset class. The overall rate for each asset class was developed by combining a long-term inflation component, the risk-free real rate of return, and the associated risk premium. A weighted average rate was developed based on those overall rates and the target asset allocation of the plan.

The Company’s pension committee is responsible for overseeing the investment of pension plan assets. The pension committee is responsible for determining and monitoring the appropriate asset allocations and for selecting or replacing investment managers, trustees, and custodians. The pension plan’s current investment target allocations are 50% equities and 50% debt. The pension committee reviews the actual asset allocation in light of these targets periodically and rebalances investments as necessary. The pension committee also evaluates the performance of investment managers as compared to the performance of specified benchmarks and peers and monitors the investment managers to ensure adherence to their stated investment style and to the plan’s investment guidelines.

Postretirement Plan - The Company also sponsors a health care plan and life insurance plan (the “Postretirement Plan”) that provides postretirement medical benefits and life insurance to certain “grandfathered” unionized employees. The Company assumed the Postretirement Plan as part of its acquisition of PE Central on July 1, 2015. Employees hired after December 31, 2000, are not eligible to participate in the Postretirement Plan. The 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.

Information related to the Postretirement Plan as of December 31, 2017 and 2016 is presented below (dollars in thousands):

	2017			2016
Amounts at the end of the year:
Accumulated/projected benefit obligation	$	5,565		$	5,371
Fair value of plan assets		—			—
Funded status, (underfunded)/overfunded	$	(5,565	)	$	(5,371	)
Amounts recognized in the consolidated balance sheets:
Accrued liabilities	$	(240	)	$	(310	)
Other liabilities	$	(5,325	)	$	(5,061	)
Accumulated other comprehensive loss	$	1,508		$	1,573

Information related to the Postretirement Plan for the years ended December 31, 2017, 2016 and 2015 is presented below (dollars in thousands):

	Years Ended December 31,
	2017			2016			2015
Amounts recognized in the plan for the year:
Company contributions	$	157		$	163		$	20
Participant contributions	$	22		$	22		$	15
Benefits paid	$	(179	)	$	(184	)	$	(35	)
Components of net periodic benefit costs are as follows:
Service cost	$	84		$	48		$	32
Interest cost		198			139			65
Amortization of prior service costs		134			—			—
Net periodic benefit cost	$	416		$	187		$	97
Loss (gain) recognized in other comprehensive income	$	(65	)	$	1,728		$	(155	)
Discount rate used in computation of benefit obligations		3.80	%		3.95	%		3.67	%

The Company does not expect to recognize any amortization of net actuarial loss during the year ended December 31, 2018.

The following table summarizes the expected benefit payments for the Company’s plan for each of the next five fiscal years and in the aggregate for the five fiscal years thereafter (in thousands):

December 31:
	2018	$	240
	2019		270
	2020		300
	2021		340
	2022		330
	2023-27		2,120
		$	3,600

For purposes of determining the cost and obligation for pre-Medicare postretirement medical benefits, a 7.0% annual rate of increase in the per capita cost of covered benefits (i.e., health care trend rate) was assumed for the plan in 2018, adjusting to a rate of 4.5% in 2026. Assumed health care cost trend rates have a significant effect on the amounts reported for health care plans.

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INCOME TAXES.

12 Months Ended

Dec. 31, 2017

Income Tax Disclosure [Abstract]

INCOME TAXES.

10. INCOME TAXES.

The Company recorded a provision (benefit) for income taxes as follows (in thousands):

	Years Ended December 31,
	2017			2016			2015
Current provision (benefit)	$	(490	)	$	141		$	(8,011	)
Deferred provision (benefit)		169			(1,122	)		(2,023	)
Total	$	(321	)	$	(981	)	$	(10,034	)

A reconciliation of the differences between the United States statutory federal income tax rate and the effective tax rate as provided in the consolidated statements of operations is as follows:

	Years Ended December 31,
	2017			2016			2015
Statutory rate		35.0	%		35.0	%		35.0	%
State income taxes, net of federal benefit		4.0			6.4			9.2
Change in valuation allowance		(34.5	)		(298.8	)		(4.2	)
Impact of Federal tax rate change on deferreds		(28.4	)		—			—
Impact of Federal tax rate change on valuation allowance		29.4			—			—
Fair value adjustments and warrant inducements		0.4			37.2			2.0
Noncontrolling interests		(3.2	)		—			—
Domestic production gross receipts deduction		—			—			(2.9	)
Section 382 reduction to loss carryover		—			—			0.1
Stock compensation		(0.1	)		58.8			(0.8	)
Non-deductible items		(0.2	)		8.9			(0.5	)
Other		(1.6	)		(27.5	)		(3.2	)
Effective rate		0.8	%		(180.0	)%		34.7	%

 Deferred income taxes are provided using the asset and liability method to reflect temporary differences between the financial statement carrying amounts and the tax bases of assets and liabilities using presently enacted tax rates and laws. The components of deferred income taxes included in the consolidated balance sheets were as follows (in thousands): 

	December 31,
	2017			2016
Deferred tax assets:
Net operating loss carryforwards	$	40,989		$	45,709
R&D and AMT credits		1,797			2,465
Railcar contracts		1,415			3,348
Stock-based compensation		738			946
Allowance for doubtful accounts and other assets		637			856
Derivatives		267			1,228
Pension liability		2,939			2,204
Other		2,097			4,316
Total deferred tax assets		50,879			61,072
Deferred tax liabilities:
Property and equipment		(25,194	)		(45,757	)
Intangibles		(749	)		(1,091	)
Other		(521	)		(1,593	)
Total deferred tax liabilities		(26,464	)		(48,441	)
Valuation allowance		(24,639	)		(12,683	)
Net deferred tax liabilities, included in other liabilities	$	(224	)	$	(52	)

A portion of the Company’s net operating loss carryforwards will be subject to provisions of the tax law that limit the use of losses incurred by a company prior to the date certain ownership changes occur. Due to the limitation, a significant portion of these net operating loss carryforwards will expire regardless of whether the Company generates future taxable income. After reducing these net operating loss carryforwards for the amount which will expire due to this limitation, the Company had remaining federal net operating loss carryforwards of approximately $154,589,000 and state net operating loss carryforwards of approximately $148,921,000 at December 31, 2017. These net operating loss carryforwards expire as follows (in thousands):

Tax Years	Federal		State
2018–2022	$	—	$	—
2023–2027		13,038		2,945
2028–2032		22,025		65,921
2033–2036		119,526		80,055
	$	154,589	$	148,921

Certain of these net operating losses are not immediately available, but become available to be utilized in each of the years ended December 31, as follows (in thousands):

Year	Federal		State
2017	$	59,675	$	82,892
2018		6,441		5,372
2019		6,374		5,345
2020		6,308		5,318
2021		6,308		5,318
Thereafter		69,483		44,676
	$	154,589	$	148,921

To the extent amounts are not utilized in any year, they may be carried forward to the next year until expiration. These amounts may change if there are future additional limitations on their utilization. 

In assessing whether the deferred tax assets are realizable, a more likely than not standard is applied. If it is determined that it is more likely than not that deferred tax assets will not be realized, a valuation allowance must be established against the deferred tax assets. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which the associated temporary differences become deductible. Management considers the scheduled reversal of deferred tax liabilities, projected future taxable income and tax planning strategies in making this assessment. 

A valuation allowance was established in the amount of $22,585,000, $12,683,000 and $39,838,000 at December 31, 2017, 2016 and 2015, respectively, based on the Company’s assessment of the future realizability of certain deferred tax assets. The valuation allowance on deferred tax assets is related to future deductible temporary differences and net operating loss carryforwards (exclusive of net operating losses associated with items recorded directly to equity) for which the Company has concluded it is more likely than not that these items will not be realized in the ordinary course of operations. 

For the year ended December 31, 2017, the Company recorded an increase in the valuation allowance of $11,956,000. This increase was primarily the offsetting impact of a decrease in deferred tax liabilities associated with property and equipment, as a result of the finalization of the deferred tax attributes of Pacific Aurora, which was subject to a 2016 sale of a noncontrolling interest. For the year ended December 31, 2016, the Company recorded a decrease in the valuation allowance of $27,155,000, including approximately $13,500,000 related to finalizing, certain aspects of the deferred tax attributes of the 2015 PE Central acquisition, and approximately $11,500,000 related to the sale of the noncontrolling interest in Pacific Aurora, which had the impact of an increase in both the net deferred tax asset and related valuation allowance. For the year ended December 31, 2015, the Company recognized $1,500,000 in tax benefit related to adjustments to its tax asset valuation allowance from a prior year. 

At December 31, 2017, the Company accrued $235,000 in tax uncertainties. There was no accrued interest or penalties relating to tax uncertainties at December 31, 2016. 

The Tax Cuts and Jobs Act (“TCJA”) was enacted on December 22, 2017. The Company recognized the income tax effects of the TCJA in its 2017 financial statements in accordance with Staff Accounting Bulletin No. 118, which provides SEC staff guidance for the application of ASC Topic 740, Income Taxes, in the reporting period in which the TCJA was signed into law. As such, the Company’s financial results reflect the income tax effects of the TCJA for which the accounting under ASC Topic 740 is complete. The Company did not identify items for which the income tax effects of the TCJA have not been completed and a reasonable estimate could not be determined as of December 31, 2017. 

Amounts recorded where accounting is complete principally relate to the reduction in the U.S. corporate income tax rate to 21%, which resulted in the Company reporting an income tax benefit of $321,000 to remeasure deferred taxes liabilities associated with indefinitely lived intangible assets that will reverse at the new 21% rate. This rate reduction decreased gross deferred assets by approximately $10,170,000 and valuation allowance by $10,545,000. Absent this deferred tax liability, the Company is in a net deferred tax asset position that is offset by a full valuation allowance, resulting in a net tax effect of zero. 

Other significant provisions of the TCJA that are not yet effective but may impact income taxes in future years include: additional limitations on certain meals and entertainment expenses, the inclusion of commissions and performance-based compensation in determining the excessive compensation limitation, limitation on the current deductibility of net interest expense in excess of 30% of adjusted taxable income, and a limitation of net operating losses generated after fiscal 2018 to 80% of taxable income.

The Company is subject to income tax in the United States federal jurisdiction and various state jurisdictions and has identified its federal tax return and tax returns in state jurisdictions below as “major” tax filings. These jurisdictions, along with the years still open to audit under the applicable statutes of limitation, are as follows: 

Jurisdiction	Tax Years
Federal	2014 – 2016
Arizona	2014 – 2016
California	2013 – 2016
Colorado	2013 – 2016
Idaho	2014 – 2016
Illinois	2014 – 2016
Indiana	2014 – 2016
Iowa	2014 – 2016
Kansas	2014 – 2016
Minnesota	2014 – 2016
Missouri	2014 – 2016
Nebraska	2014 – 2016
Oklahoma	2014 – 2016
Oregon	2014 – 2016
Texas	2013 – 2016

However, because the Company had net operating losses and credits carried forward in several of the jurisdictions, including the United States federal and California jurisdictions, certain items attributable to closed tax years are still subject to adjustment by applicable taxing authorities through an adjustment to tax attributes carried forward to open years.

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PREFERRED STOCK.

12 Months Ended

Dec. 31, 2017

Equity [Abstract]

PREFERRED STOCK.

11. PREFERRED STOCK.

The Company has 6,734,835 undesignated shares of authorized and unissued preferred stock, which may be designated and issued in the future on the authority of the Company’s Board of Directors. As of December 31, 2017, the Company had the following designated preferred stock:

Series A Preferred Stock – The Company has authorized 1,684,375 shares of Series A Cumulative Redeemable Convertible Preferred Stock (“Series A Preferred Stock”), with none outstanding at December 31, 2017 and 2016. Shares of Series A Preferred Stock that are converted into shares of the Company’s common stock revert to undesignated shares of authorized and unissued preferred stock.

Upon any issuance, the Series A Preferred Stock would rank senior in liquidation and dividend preferences to the Company’s common stock. Holders of Series A Preferred Stock would be entitled to quarterly cumulative dividends payable in arrears in cash in an amount equal to 5% per annum of the purchase price per share of the Series A Preferred Stock. The holders of the Series A Preferred Stock would have conversion rights initially equivalent to two shares of common stock for each share of Series A Preferred Stock, subject to customary antidilution adjustments. Certain specified issuances will not result in antidilution adjustments. The shares of Series A Preferred Stock would also be subject to forced conversion upon the occurrence of a transaction that would result in an internal rate of return to the holders of the Series A Preferred Stock of 25% or more. Accrued but unpaid dividends on the Series A Preferred Stock are to be paid in cash upon any conversion of the Series A Preferred Stock.

The holders of Series A Preferred Stock would have a liquidation preference over the holders of the Company’s common stock equivalent to the purchase price per share of the Series A Preferred Stock plus any accrued and unpaid dividends on the Series A Preferred Stock. A liquidation would be deemed to occur upon the happening of customary events, including transfer of all or substantially all of the Company’s capital stock or assets or a merger, consolidation, share exchange, reorganization or other transaction or series of related transactions, unless holders of 66 2/3% of the Series A Preferred Stock vote affirmatively in favor of or otherwise consent to such transaction.

Series B Preferred Stock – The Company has authorized 1,580,790 shares of Series B Cumulative Convertible Preferred Stock (“Series B Preferred Stock”), with 926,942 shares outstanding at December 31, 2017 and 2016. Shares of Series B Preferred Stock that are converted into shares of the Company’s common stock revert to undesignated shares of authorized and unissued preferred stock.

The Series B Preferred Stock ranks senior in liquidation and dividend preferences to the Company’s common stock. Holders of Series B Preferred Stock are entitled to quarterly cumulative dividends payable in arrears in cash in an amount equal to 7.00% per annum of the purchase price per share of the Series B Preferred Stock; however, subject to the provisions of the Letter Agreement described below, such dividends may, at the option of the Company, be paid in additional shares of Series B Preferred Stock based initially on the liquidation value of the Series B Preferred Stock. In addition to the quarterly cumulative dividends, holders of the Series B Preferred Stock are entitled to participate in any common stock dividends declared by the Company to its common stockholders. The holders of Series B Preferred Stock have a liquidation preference over the holders of the Company’s common stock initially equivalent to $19.50 per share of the Series B Preferred Stock plus any accrued and unpaid dividends on the Series B Preferred Stock. A liquidation will be deemed to occur upon the happening of customary events, including the transfer of all or substantially all of the capital stock or assets of the Company or a merger, consolidation, share exchange, reorganization or other transaction or series of related transaction, unless holders of 66 2/3% of the Series B Preferred Stock vote affirmatively in favor of or otherwise consent that such transaction shall not be treated as a liquidation. The Company believes that such liquidation events are within its control and therefore has classified the Series B Preferred Stock in stockholders’ equity.

As of December 31, 2017, the Series B Preferred Stock was convertible into 634,641 shares of the Company’s common stock. The conversion ratio is subject to customary antidilution adjustments. In addition, antidilution adjustments are to occur in the event that the Company issues equity securities, including derivative securities convertible into equity securities (on an as-converted or as-exercised basis), at a price less than the conversion price then in effect. The shares of Series B Preferred Stock are also subject to forced conversion upon the occurrence of a transaction that would result in an internal rate of return to the holders of the Series B Preferred Stock of 25% or more. The forced conversion is to be based upon the conversion ratio as last adjusted. Accrued but unpaid dividends on the Series B Preferred Stock are to be paid in cash upon any conversion of the Series B Preferred Stock.

The holders of Series B Preferred Stock vote together as a single class with the holders of the Company’s common stock on all actions to be taken by the Company’s stockholders. Each share of Series B Preferred Stock entitles the holder to approximately 0.03 votes per share on all matters to be voted on by the stockholders of the Company. Notwithstanding the foregoing, the holders of Series B Preferred Stock are afforded numerous customary protective provisions with respect to certain actions that may only be approved by holders of a majority of the shares of Series B Preferred Stock.

In 2008, the Company entered into Letter Agreements with Lyles United LLC (“Lyles United”) and other purchasers under which the Company expressly waived its rights under the Certificate of Designations relating to the Series B Preferred Stock to make dividend payments in additional shares of Series B Preferred Stock in lieu of cash dividend payments without the prior written consent of Lyles United and the other purchasers.

Registration Rights Agreement – In connection with the sale of its Series B Preferred Stock, the Company entered into a registration rights agreement with Lyles United. The registration rights agreement is to be effective until the holders of the Series B Preferred Stock, and their affiliates, as a group, own less than 10% for each of the series issued, including common stock into which such Series B Preferred Stock has been converted. The registration rights agreement provides that holders of a majority of the Series B Preferred Stock, including common stock into which such Series B Preferred Stock has been converted, may demand and cause the Company to register on their behalf the shares of common stock issued, issuable or that may be issuable upon conversion of the Preferred Stock and as payment of dividends thereon, and upon exercise of the related warrants (collectively, the “Registrable Securities”). The Company is required to keep such registration statement effective until such time as all of the Registrable Securities are sold or until such holders may avail themselves of Rule 144 for sales of Registrable Securities without registration under the Securities Act of 1933, as amended. The holders are entitled to two demand registrations on Form S-1 and unlimited demand registrations on Form S-3; provided, however, that the Company is not obligated to effect more than one demand registration on Form S-3 in any calendar year. In addition to the demand registration rights afforded the holders under the registration rights agreement, the holders are entitled to unlimited “piggyback” registration rights. These rights entitle the holders who so elect to be included in registration statements to be filed by the Company with respect to other registrations of equity securities. The Company is responsible for all costs of registration, plus reasonable fees of one legal counsel for the holders, which fees are not to exceed $25,000 per registration. The registration rights agreement includes customary representations and warranties on the part of both the Company and the holders and other customary terms and conditions.

The Company accrued and paid in cash preferred stock dividends of $1,265,000, $1,269,000 and $1,265,000 for the years ended December 31, 2017, 2016 and 2015, respectively.

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COMMON STOCK AND WARRANTS.

12 Months Ended

Dec. 31, 2017

Stockholders' Equity Note [Abstract]

COMMON STOCK AND WARRANTS.

12. COMMON STOCK AND WARRANTS.

The following table summarizes warrant activity for the years ended December 31, 2017, 2016 and 2015 (number of shares in thousands):

	Number of Shares			Price per Share	Weighted Average Exercise Price
Balance at December 31, 2014		856		$6.09 – $735.00	$	36.55
Warrants exercised		(42	)	$8.85	$	8.85
Warrants expired		(432	)	$8.85	$	8.85
Balance at December 31, 2015		382		$6.09 – $735.00	$	70.87
Warrants exercised		(138	)	$8.43	$	8.43
Balance at December 31, 2016		244		$6.09 – $735.00	$	106.72
Warrants exercised		(191	)	$6.09	$	6.09
Warrants expired		(49	)	$6.09 – $735.00	$	444.00
Balance at December 31, 2017		4		$735.00	$	735.00

July 2012 Public Offering – On July 3, 2012, in connection with a public offering, the Company issued warrants to purchase an aggregate of 1,867,000 shares of the Company’s common stock. The warrants were issued at an initial exercise price of $9.45 per share, which was subject to certain “weighted-average” anti-dilution adjustments. As a result of anti-dilution adjustments, the exercise price was reduced to $6.09 per share. The balance of these warrants expired unexercised in 2017.

Accounting for Warrants – The Company determined that certain warrants issued in 2011 and 2012 did not meet the conditions for classification in stockholders’ equity and, as such, the Company recorded them as a liability at fair value. The Company revalued them at each reporting period. Accordingly, the Company recorded fair value adjustments quarterly, with total fair value adjustments of $473,000, $(557,000) and $1,641,000 of income (expense) for the years ended December 31, 2017, 2016 and 2015, respectively, which was largely attributed to adjustments to their exercise prices, term shortening and changes in the market value of the Company’s common stock. See Note 15 for the Company’s fair value assumptions. As of December 31, 2017, there were no warrants outstanding for which the Company accounts using fair value methodologies. Accordingly, no fair value adjustments will be made in the future periods related to currently outstanding warrants.

Nonvoting Common Stock – In connection with the Company’s PE Central acquisition, the Company issued nonvoting common shares exercisable at the holders’ election. During the year ended December 31, 2017, 3,539,236 shares of nonvoting common stock were exchanged for an equal number of shares of the Company’s common stock upon the holders’ request.

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STOCK BASED COMPENSATION.

12 Months Ended

Dec. 31, 2017

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

STOCK-BASED COMPENSATION.

13. STOCK-BASED COMPENSATION.

The Company has two equity incentive compensation plans: a 2006 Stock Incentive Plan and a 2016 Stock Incentive Plan.

2006 Stock Incentive Plan – The 2006 Stock Incentive Plan authorized the issuance of incentive stock options (“ISOs”) and non-qualified stock options (“NQOs”), restricted stock, restricted stock units, stock appreciation rights, direct stock issuances and other stock-based awards to the Company’s officers, directors or key employees or to consultants that do business with the Company for up to an aggregate of 1,715,000 shares of common stock. In June 2016, this plan was terminated, except to the extent of issued and outstanding unvested stock awards and options.

2016 Stock Incentive Plan – On June 16, 2016, the Company’s shareholders approved the 2016 Stock Incentive Plan, which authorizes the issuance of ISOs, NQOs, restricted stock, restricted stock units, stock appreciation rights, direct stock issuances and other stock-based awards to the Company’s officers, directors or key employees or to consultants that do business with the Company for up to an aggregate of 1,150,000 shares of common stock.

Stock Options – Summaries of the status of Company’s stock option plans as of December 31, 2017 and 2016 and of changes in options outstanding under the Company’s plans during those years are as follows (number of shares in thousands):

	Years Ended December 31,
	2017					2016
	Number of Shares			Weighted Average Exercise Price		Number of Shares		Weighted Average Exercise Price
Outstanding at beginning of year		240		$	4.18		240	$	4.18
Exercised		(10	)		3.74		—		—
Outstanding at end of year		230		$	4.18		240	$	4.18
Options exercisable at end of year		230		$	4.18		240	$	4.18

Stock options outstanding as of December 31, 2017 were as follows (number of shares in thousands): 

		Options Outstanding				Options Exercisable
	Range of Exercise Prices	Number  Outstanding	Weighted Average Remaining Contractual Life (yrs.)		Weighted Average   Exercise  Price	Number Exercisable		Weighted  Average  Exercise  Price
$	3.74	219	5.47	$	3.74	219	$	3.74
$	12.90	11	3.59	$	12.90	11	$	12.90

The options outstanding at December 31, 2017 and 2016 had intrinsic values of $84,000 and $1,319,000, respectively. The intrinsic value of options exercised in 2017 was approximately $30,000.

Restricted Stock – The Company granted to certain employees and directors shares of restricted stock under its 2006 and 2016 Stock Incentive Plans. A summary of unvested restricted stock activity is as follows (shares in thousands):

	Number of Shares			Weighted Average Grant Date  Fair Value Per Share
Unvested at December 31, 2014		390		$	8.71
Issued		307		$	10.16
Vested		(220	)	$	7.94
Canceled		(14	)	$	10.08
Unvested at December 31, 2015		463		$	10.00
Issued		742		$	5.24
Vested		(250	)	$	9.01
Canceled		(25	)	$	6.24
Unvested at December 31, 2016		930		$	6.57
Issued		664		$	6.65
Vested		(480	)	$	7.30
Canceled		(37	)	$	6.08
Unvested at December 31, 2017		1,077		$	6.31

The fair value of the common stock at vesting aggregated $3,210,000, $1,142,000 and $2,603,000 for the years ended December 31, 2017, 2016 and 2015, respectively. Stock-based compensation expense related to employee and non-employee restricted stock and option grants recognized in selling, general and administrative expenses, were as follows (in thousands):

	Years Ended December 31,
	2017		2016		2015
Employees	$	3,303	$	2,173	$	1,694
Non-employees		525		443		325
Total stock-based compensation expense	$	3,828	$	2,616	$	2,019

Employee grants typically have a three year vesting schedule, while the non-employee grants have a one year vesting schedule. At December 31, 2017, the total compensation expense related to unvested awards which had not been recognized was $4,122,000 and the associated weighted-average period over which the compensation expense attributable to those unvested awards will be recognized was approximately 1.54 years.

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COMMITMENTS AND CONTINGENCIES.

12 Months Ended

Dec. 31, 2017

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES.

14. COMMITMENTS AND CONTINGENCIES.

Commitments – The following is a description of significant commitments at December 31, 2017:

Leases – Future minimum lease payments required by non-cancelable leases in effect at December 31, 2017 were as follows (in thousands):

Years Ended December 31,	Capital Leases			Operating Leases
2018	$	613		$	11,841
2019		45			9,236
2020		45			7,042
2021		34			4,074
2022		—			3,894
Thereafter		—			5,530
Total minimum payments		737		$	41,617
Amount representing interest		(22	)
Obligations under capital leases		715
Obligations due within one year		(592	)
Long-term obligations under capital leases	$	123

Total rent expense during the years ended December 31, 2017, 2016 and 2015 was $16,572,000, $16,253,000 and $10,476,000, respectively.

Sales Commitments – The Company had open ethanol indexed-price contracts for 310,289,000 gallons of ethanol as of December 31, 2017 and open fixed-price ethanol sales contracts totaling $90,389,000 as of December 31, 2017. The Company had open fixed-price co-product sales contracts totaling $35,600,000 as of December 31, 2017. These sales contracts are scheduled to be completed throughout 2018.

Purchase Commitments – At December 31, 2017, the Company had indexed-price purchase contracts to purchase 16,149,000 gallons of ethanol and fixed-price purchase contracts to purchase $8,932,000 of ethanol from its suppliers. The Company had fixed-price purchase contracts to purchase $21,134,000 of corn from its suppliers. These purchase commitments are scheduled to be satisfied throughout 2018. 

Property Tax Assessment – In September 2016, the Company signed an agreement to finance and construct a 5 megawatt solar project at its Madera facility. The amount financed is for up to $10.0 million, to be amortized over twenty years as part of the facility’s property tax assessments. As of December 31, 2017, the Company had incurred $7.7 million in project costs, which is recorded in construction in progress and in other liabilities in the accompanying consolidated balance sheets. The Company expects to pay an additional $0.9 million per year in connection with its property tax payments, which includes an interest component based upon a 5.6% interest rate on the outstanding balance of the assessment.

Other Commitments – At December 31, 2017, the Company had firm commitments for various capital and process improvement projects at the Company’s plants of approximately $4,100,000, which are expected to be completed in 2018.

Contingencies – The following is a description of significant contingencies at December 31, 2017:

Litigation – 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 financial impact on the Company’s operating results.

The Company assumed certain legal matters which were ongoing at July 1, 2015, the date of the Company’s acquisition of 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 PE Central 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 as a reduction to selling, general and administrative expenses in the consolidated statements of operations for the year ended December 31, 2017.

Pacific Ethanol, Inc., through a subsidiary acquired in its acquisition of PE Central, became involved in a pending lawsuit with Western Sugar Cooperative (“Western Sugar”) that pre-dated the acquisition. On February 27, 2015, Western Sugar filed a complaint in the United States District Court for the District of Colorado (Case No. 1:15-cv-00415) naming PE Central’s subsidiary as defendant. The PE Central subsidiary purchased surplus sugar through a United States Department of Agriculture program. Western Sugar was one of the entities that warehoused this sugar for the PE Central subsidiary. The suit alleged that the PE Central subsidiary breached its contract with Western Sugar by failing to pay certain penalty rates for the storage of its sugar or alternatively failing to pay a premium rate for storage. Western Sugar alleged that the penalty rates applied because the PE Central subsidiary failed to take timely delivery or otherwise cause timely shipment of the sugar. Western Sugar claimed “expectation damages” in the amount of approximately $8.6 million. On December 29, 2016, Western Sugar and the PE Central subsidiary entered into a settlement pursuant to which the PE Central subsidiary paid $1.7 million and Western Sugar filed a Stipulation of Dismissal with prejudice. As a result, the Company reduced its litigation reserve of $2.8 million and recognized the recovery of $1.1 million as a reduction to selling, general and administrative expenses for the year ended December 31, 2016.

On May 24, 2013, GS CleanTech Corporation (“GS CleanTech”), filed a suit in the United States District Court for the Eastern District of California, Sacramento Division (Case No.: 2:13-CV-01042-JAM-AC), naming Pacific Ethanol, Inc. as a defendant. On August 29, 2013, the case was transferred to the United States District Court for the Southern District of Indiana and made part of the pre-existing multi-district litigation involving GS CleanTech and multiple defendants. The suit alleged infringement of a patent assigned to GS CleanTech by virtue of certain corn oil separation technology in use at one or more of the ethanol production facilities in which the Company has an interest, including Pacific Ethanol Stockton LLC (“PE Stockton”), located in Stockton, California. The complaint sought preliminary and permanent injunctions against the Company, prohibiting future infringement on the patent owned by GS CleanTech and damages in an unspecified amount adequate to compensate GS CleanTech for the alleged patent infringement, but in any event no less than a reasonable royalty for the use made of the inventions of the patent, plus attorneys’ fees. The Company answered the complaint, counterclaimed that the patent claims at issue, as well as the claims in several related patents, are invalid and unenforceable and that the Company is not infringing. Pacific Ethanol, Inc. does not itself use any corn oil separation technology and may seek a dismissal on those grounds.

On March 17 and March 18, 2014, GS CleanTech filed suit naming as defendants two Company subsidiaries: PE Stockton and Pacific Ethanol Magic Valley, LLC (“PE Magic Valley”). The claims were similar to those filed against Pacific Ethanol, Inc. in May 2013. These two cases were transferred to the multi-district litigation division in United States District Court for the Southern District of Indiana, where the case against Pacific Ethanol, Inc. was pending. Although PE Stockton and PE Magic Valley do separate and market corn oil, Pacific Ethanol, Inc., PE Stockton and PE Magic Valley strongly disagree that either of the subsidiaries use corn oil separation technology that infringes the patent owned by GS CleanTech. In a January 16, 2015 decision, the District Court for the Southern District of Indiana ruled in favor of a stipulated motion for partial summary judgment for Pacific Ethanol, Inc., PE Stockton and PE Magic Valley finding that all of the GS CleanTech patents in the suit were invalid and, therefore, not infringed.

A trial in the District Court for the Southern District of Indiana was conducted in October 2015 on the inequitable conduct issue as well as whether GS CleanTech’s behavior during prosecution of the patents rendered this an “exceptional case” which would allow the District Court to award the Defendants reimbursement of their attorneys’ fees expended for defense of the case.

On September 15, 2016, the District Court issued an Order finding that GS CleanTech, the inventors and GS CleanTech’s counsel committed inequitable conduct in the prosecution of the GS CleanTech patents before the United States Patent and Trademark Office. As a result, the District Court issued a Final Judgment on September 15, 2016 dismissing with prejudice all of GS CleanTech’s cases against the Defendants, including Pacific Ethanol, Inc., PE Stockton and PE Magic Valley. The District Court’s ruling of inequitable conduct results in the unenforceability of the GS CleanTech patents against third parties, and also enables the Defendants to pursue reimbursement of their costs and attorneys’ fees from GS CleanTech and its counsel. GS CleanTech subsequently appealed the District Court’s finding that all of the GS CleanTech patents were invalid and its finding that the inventors and GS CleanTech’s counsel committed inequitable conduct. The Court of Appeals for the Federal Circuit ordered the appeals stayed until June 15, 2018, pending rulings on certain procedural motions.

The Company has evaluated the above cases as well as other pending cases. The Company currently has not recorded a litigation contingency liability with respect to these cases.

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FAIR VALUE MEASUREMENTS.

12 Months Ended

Dec. 31, 2017

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS.

15.  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.

Pooled separate accounts – Pooled separate accounts invest primarily in domestic and international stocks, commercial paper or single mutual funds. The net asset value is used as a practical expedient to determine fair value for these accounts. Each pooled separate account provides for redemptions by the Retirement Plan at reported net asset values per share, with little to no advance notice requirement, therefore these funds are classified within Level 2 of the valuation hierarchy. 

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 from 2011 through 2012 at fair value and designated them as Level 3 on their issuance dates. All of such warrants were retired as of December 31, 2017. 

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 December 31, 2017 (in thousands):

											Benefit Plan
	Fair										Percentage
	Value			Level 1			Level 2		Level 3		Allocation
Assets:
Derivative financial instruments(1)	$	998		$	998		$	—	$	—
Defined benefit plan assets(2) (pooled separate accounts):
Large U.S. Equity(3)		3,748			—			3,748		—		27	%
Small/Mid U.S. Equity(4)		2,018			—			2,018		—		14	%
International Equity(5)		2,528			—			2,528		—		18	%
Fixed Income(6)		5,664			—			5,664		—		41	%
	$	14,956		$	998		$	13,958	$	—
Liabilities:
Derivative financial instruments(7)	$	(2,307	)	$	(2,307	)	$	—	$	—

The following table summarizes recurring fair value measurements by level at December 31, 2016 (in thousands):

												Benefit Plan
	Fair											Percentage
	Value			Level 1			Level 2		Level 3			Allocation
Assets:
Derivative financial instruments(1)	$	978		$	978		$	—	$	—
Defined benefit plan assets(2) (pooled separate accounts):
Large U.S. Equity(3)		3,134			—			3,134		—			25	%
Small/Mid U.S. Equity(4)		1,802			—			1,802		—			15	%
International Equity(5)		2,006			—			2,006		—			16	%
Fixed Income(6)		5,481			—			5,481		—			44	%
	$	13,401		$	978		$	12,423	$	—
Liabilities:
Warrants(8)	$	(651	)	$	—		$	—	$	(651	)
Derivative financial instruments(7)		(4,115	)		(4,115	)		—		—
	$	(4,766	)	$	(4,115	)	$	—	$	(651	)

(1) Included in derivative assets in the consolidated balance sheets.

(2) See Note 9 for accounting discussion.

(3) This category includes investments in funds comprised of equity securities of large U.S. companies. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(4) This category includes investments in funds comprised of equity securities of small- and medium-sized U.S. companies. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(5) This category includes investments in funds comprised of equity securities of foreign companies including emerging markets. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(6) This category includes investments in funds comprised of U.S. and foreign investment-grade fixed income securities, high-yield fixed income securities that are rated below investment-grade, U.S. treasury securities, mortgage-backed securities, and other asset-backed securities. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(7) Included in derivative liabilities in the consolidated balance sheets.

(8) Included in warrant liabilities at fair value in the consolidated balance sheets.

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

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

	Warrants
Balance, December 31, 2014	$	1,986
Exercises of warrants		(72	)
Expiration of warrants		(527	)
Adjustments to fair value for the period		(1,114	)
Balance, December 31, 2015	$	273
Exercises of warrants		(179	)
Adjustments to fair value for the period		557
Balance, December 31, 2016	$	651
Exercises of warrants		(178	)
Adjustments to fair value for the period		(473	)
Balance, December 31, 2017	$	—	\

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PARENT COMPANY FINANCIALS.

12 Months Ended

Dec. 31, 2017

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

PARENT COMPANY FINANCIALS.

16. PARENT COMPANY FINANCIALS.

Restricted Net Assets – At December 31, 2017, the Company had approximately $302,900,000 of net assets at its subsidiaries that were not available to be transferred to Pacific Ethanol in the form of dividends, distributions, loans or advances due to restrictions contained in the credit facilities of these subsidiaries.

Parent company financial statements for the periods covered in this report are set forth below.

	December 31,
	2017			2016
ASSETS
Current Assets:
Cash and cash equivalents	$	5,314		$	11,060
Receivables from subsidiaries		3,138			7,203
Other current assets		1,631			6,442
Total current assets		10,083			24,705
Property and equipment, net		1,071			1,433
Other Assets:
Investments in subsidiaries		359,680			363,401
Pacific Ethanol West plant receivable		58,766			58,766
Other assets		1,565			1,110
Total other assets		420,011			423,277
Total Assets	$	431,165		$	449,415
Current Liabilities:
Accounts payable and accrued liabilities	$	2,218		$	1,758
Payable to subsidiaries		625			1,568
Accrued PE Op Co. purchase		3,828			3,828
Other current liabilities		245			184
Total current liabilities		6,916			7,338
Long-term debt, net		67,530			53,360
Warrant liabilities at fair value		—			651
Deferred tax liabilities		224			52
Other liabilities		56			124
Total Liabilities		74,726			61,525
Stockholders’ Equity:
Preferred stock		1			1
Common and non-voting common stock		44			44
Additional paid-in capital		927,090			922,698
Accumulated other comprehensive loss		(2,234	)		(2,620	)
Accumulated deficit		(568,462	)		(532,233	)
Total Pacific Ethanol, Inc. stockholders’ equity		356,439			387,890
Total Liabilities and Stockholders’ Equity	$	431,165		$	449,415

	Years Ended December 31,
	2017			2016			2015
Management fees from subsidiaries	$	11,904		$	12,968		$	9,857
Selling, general and administrative expenses		18,185			14,491			14,336
Asset impairment		—			—			1,970
Loss from operations		(6,281	)		(1,523	)		(6,449	)
Fair value adjustments		473			(557	)		1,641
Interest income		4,793			5,964			5,739
Interest expense		(5,829	)		(240	)		(27	)
Other income (expense), net		(95	)		1,931			—
Income (loss) before provision for income taxes		(6,939	)		5,575			904
Provision (benefit) for income taxes		(321	)		(981	)		(10,034	)
Income (loss) before equity in earnings of subsidiaries		(6,618	)		6,556			10,938
Equity in losses of subsidiaries		(28,346	)		(5,137	)		(29,724	)
Consolidated net income (loss)	$	(34,964	)	$	1,419		$	(18,786	)

	For the Years Ended December 31,
	2017			2016			2015
Operating Activities:
Net income (loss)	$	(34,964	)	$	1,419		$	(18,786	)
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Equity in losses of subsidiaries		28,346			5,137			29,724
Dividends from subsidiaries		3,500			—			—
Depreciation and amortization		830			727			390
Fair value adjustments		(473	)		557			(1,641	)
Asset impairment		—			—			1,970
Deferred income taxes		169			(1,122	)		(14,260	)
Amortization of debt discounts		636			10			—
Changes in operating assets and liabilities:
Accounts receivables		4,065			7,302			(5,958	)
Other assets		4,356			4,647			(4,139	)
Accounts payable and accrued expenses		3,859			(3,741	)		604
Accounts payable with subsidiaries		(943	)		(9,385	)		11,179
Net cash provided by (used in) operating activities	$	9,381		$	5,551		$	(917	)
Investing Activities:
Additions to property and equipment	$	(468	)	$	(465	)	$	(1,483	)
Investments in subsidiaries		(28,126	)		(50,886	)		—
Purchase of PE OP Co. debt		—			(17,003	)		—
Net cash used in investing activities	$	(28,594	)	$	(68,354	)	$	(1,483	)
Financing Activities:
Proceeds from issuances of senior notes	$	13,530		$	53,350		$	—
Proceeds from warrant stock option exercises		1,202			1,164			368
Preferred stock dividend payments		(1,265	)		(1,269	)		(1,265	)
Net cash provided by (used in) financing activities	$	13,467		$	53,245		$	(897	)
Net decrease in cash and cash equivalents		(5,746	)		(9,558	)		(3,297	)
Cash and cash equivalents at beginning of period		11,060			20,618			23,915
Cash and cash equivalents at end of period	$	5,314		$	11,060		$	20,618

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QUARTERLY FINANCIAL DATA (UNAUDITED).

12 Months Ended

Dec. 31, 2017

Quarterly Financial Information Disclosure [Abstract]

QUARTERLY FINANCIAL DATA (UNAUDITED).

17. QUARTERLY FINANCIAL DATA (UNAUDITED).

The Company’s quarterly results of operations for the years ended December 31, 2017 and 2016 are as follows (in thousands). Certain of these calculations have been revised from the calculations previously reported to reflect the participating securities.

	First Quarter			Second Quarter			Third Quarter			Fourth Quarter
December 31, 2017:
Net sales	$	386,340		$	405,202		$	445,442		$	395,271
Gross profit (loss)	$	(5,773	)	$	1,653		$	12,065		$	(2,014	)
Income (loss) from operations	$	(11,223	)	$	(7,109	)	$	3,345		$	(10,598	)
Net loss attributed to Pacific Ethanol, Inc.	$	(12,636	)	$	(8,841	)	$	(202	)	$	(13,285	)
Preferred stock dividends	$	(312	)	$	(315	)	$	(319	)	$	(319	)
Net loss available to common stockholders	$	(12,948	)	$	(9,156	)	$	(521	)	$	(13,604	)
Basic and diluted loss per common share	$	(0.31	)	$	(0.22	)	$	(0.01	)	$	(0.32	)
	First Quarter			Second Quarter			Third Quarter			Fourth Quarter
December 31, 2016:
Net sales	$	342,373		$	422,860		$	417,806		$	441,719
Gross profit	$	1,668		$	18,355		$	7,021		$	27,314
Income (loss) from operations	$	(7,248	)	$	11,556		$	393		$	18,808
Net income (loss) attributed to Pacific Ethanol, Inc.	$	(13,226	)	$	5,086		$	(3,518	)	$	13,077
Preferred stock dividends	$	(315	)	$	(315	)	$	(319	)	$	(320	)
Income allocated to participating securities	$	—		$	(71	)	$	—		$	(189	)
Net income (loss) available to common stockholders	$	(13,541	)	$	4,700		$	(3,837	)	$	12,569
Basic and diluted income (loss) per common share	$	(0.32	)	$	0.11		$	(0.09	)	$	0.30

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ORGANIZATION AND SIGNIFICANT ACCOUNTING POLICIES. (Policies)

12 Months Ended

Dec. 31, 2017

Organization, Consolidation and Presentation of Financial Statements [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”) and PE Op Co., a Delaware corporation (“PE Op Co.”).

The Company’s acquisition of Aventine Renewable Energy Holdings, Inc. (now, Pacific Ethanol Central, LLC, a Delaware limited liability company, “PE Central”) was consummated on July 1, 2015, and as a result, the Company’s consolidated financial statements include the results of PE Central only as of and for the years ended December 31, 2017 and 2016 and for the six months ended December 31, 2015.

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, the Company owned 73.93% of Pacific Aurora and ACEC owned 26.07% of Pacific Aurora as of December 31, 2017 and 2016. Further, the Company has consolidated 100% of the results of Pacific Aurora and recorded ACEC’s 26.07% equity interest as noncontrolling interests in the accompanying financial statements for the year ended December 31, 2017 and for the period December 15, 2016 through December 31, 2016.

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 only for the period from July 3, 2017 through December 31, 2017.

The Company is a leading producer and marketer of low-carbon renewable fuels in the United States. 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.

With the addition of four Midwestern ethanol plants in July 2015 as a result of the Company’s acquisition of PE Central and the addition of ICP’s plant in July 2017, the Company now has a combined production capacity of 605 million gallons per year, markets, on an annualized basis, nearly 1.0 billion gallons of ethanol and specialty alcohols, and produces, on an annualized basis, over 3.0 million tons of co-products on a dry matter basis, 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 allows for greater access to international markets.

As of December 31, 2017, all nine facilities were operating. As market conditions change, the Company may increase, decrease or idle production at one or more operational facilities or resume operations at any idled facility.

Basis of Presentation

Basis of Presentation – The consolidated financial statements and related notes have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) and include the accounts of the Company. All significant intercompany accounts and transactions have been eliminated in consolidation.

Segments

Segments – A segment is a component of an enterprise whose operating results are regularly reviewed by the enterprise’s chief operating decision maker to make decisions about resources to be allocated to the segment and assess its performance, and for which discrete financial information is available. The Company determines and discloses its segments in accordance with the Financial Accounting Standards Board’s (“FASB”) Accounting Standards Codification Section 280, Segment Reporting, which defines how to determine segments. The Company reports its financial and operating performance in two reportable 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.

Cash and Cash Equivalents

Cash and Cash Equivalents – The Company considers all highly-liquid investments with an original maturity of three months or less to be cash equivalents. The Company maintains its accounts at several financial institutions. These cash balances regularly exceed amounts insured by the Federal Deposit Insurance Corporation, however, the Company does not believe it is exposed to any significant credit risk on these balances.

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. Due to a limited number of ethanol customers, the Company had significant concentrations of credit risk from sales of ethanol as of December 31, 2017 and 2016, as described below.

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 $64,501,000 and $64,853,000 at December 31, 2017 and 2016, respectively, were used as collateral under Kinergy’s operating line of credit. The allowance for doubtful accounts was $19,000 and $331,000 as of December 31, 2017 and 2016, respectively. The Company recorded a bad debt expense of $5,000 and $306,000 and a recovery of $354,000 for the years ended December 31, 2017, 2016 and 2015, respectively. The Company does not have any off-balance sheet credit exposure related to its customers.

Concentration Risks

Concentration Risks – Credit risk represents the accounting loss that would be recognized at the reporting date if counterparties failed completely to perform as contracted. Concentrations of credit risk, whether on- or off-balance sheet, that arise from financial instruments exist for groups of customers or counterparties when they have similar economic characteristics that would cause their ability to meet contractual obligations to be similarly affected by changes in economic or other conditions described below. Financial instruments that subject the Company to credit risk consist of cash balances maintained in excess of federal depository insurance limits and accounts receivable, which have no collateral or security. The Company has not experienced any significant losses in such accounts and believes that it is not exposed to any significant risk of loss of cash.

The Company sells fuel-grade ethanol to gasoline refining and distribution companies. The Company sold ethanol to customers representing 10% or more of the Company’s total net sales, as follows.

	Years Ended December 31,
	2017			2016			2015
Customer A		16	%		17	%		12	%
Customer B		11	%		12	%		15	%
Customer C		6	%		6	%		12	%

The Company had accounts receivable due from these customers totaling $21,584,000 and $21,274,000, representing 27% and 25% of total accounts receivable, as of December 31, 2017 and 2016, respectively.

The Company purchases corn, its largest cost component in producing ethanol, from its suppliers. The Company purchased corn from suppliers representing 10% or more of the Company’s total corn purchases, as follows:

	Years Ended December 31,
	2017			2016			2015
Supplier A		14	%		13	%		19	%
Supplier B		13	%		4	%		—	%
Supplier C		10	%		8	%		9	%
Supplier D		9	%		13	%		13	%

Approximately 32% of the Company’s employees are covered by a collective bargaining agreement.

Inventories

Inventories – Inventories consisted primarily of bulk ethanol, specialty alcohols, corn, co-products, low-carbon and Renewable Identification Number (“RIN”) credits and unleaded fuel, and are valued at the lower-of-cost-or-net realizable value, with cost determined on a first-in, first-out basis. Inventory is net of a $2.7 million valuation adjustment as of December 31, 2017. Inventory balances consisted of the following (in thousands):

	December 31,
	2017		2016
Finished goods	$	35,652	$	33,773
Work in progress		8,807		7,092
Raw materials		7,601		6,571
Low-carbon and RIN credits		7,952		10,926
Other		1,538		1,708
Total	$	61,550	$	60,070

Property and Equipment

Property and Equipment – Property and equipment are stated at cost. Depreciation is computed using the straight-line method over the following estimated useful lives: 

Buildings	40 years
Facilities and plant equipment	10 – 25 years
Other equipment, vehicles and furniture	5 – 10 years

The cost of normal maintenance and repairs is charged to operations as incurred. Significant capital expenditures that increase the life of an asset are capitalized and depreciated over the estimated remaining useful life of the asset. The cost of property and equipment sold, or otherwise disposed of, and the related accumulated depreciation or amortization are removed from the accounts, and any resulting gains or losses are reflected in current operations.

Intangible Assets

Intangible Asset – The Company assesses indefinite-lived intangible assets for impairment annually, or more frequently if circumstances indicate impairment may have occurred. If the carrying value of an indefinite-lived intangible asset exceeds its fair value, an impairment loss is recognized in an amount equal to that excess. If the Company determines that an impairment charge is needed, the charge will be recorded as an asset impairment in the consolidated statements of operations.

Derivative Instruments and Hedging Activities

Derivative Instruments and Hedging Activities – Derivative transactions, which can include exchange-traded forward contracts and futures positions on the New York Mercantile Exchange or the Chicago Board of Trade, are recorded on the balance sheet as assets and liabilities based on the derivative’s fair value. Changes in the fair value of derivative contracts are recognized currently in income unless specific hedge accounting criteria are met. If derivatives meet those criteria, and hedge accounting is elected, effective gains and losses are deferred in accumulated other comprehensive income (loss) and later recorded together with the hedged item in consolidated income (loss). For derivatives designated as a cash flow hedge, the Company formally documents the hedge and assesses the effectiveness with associated transactions. The Company has designated and documented contracts for the physical delivery of commodity products to and from counterparties as normal purchases and normal sales.

Revenue Recognition

Revenue Recognition – The Company recognizes revenue when it is realized or realizable and earned. The Company considers revenue realized or realizable and earned when there is persuasive evidence of an arrangement, delivery has occurred, the sales price is fixed or determinable, and collection is reasonably assured. The Company derives revenue primarily from sales of ethanol and related co-products. The Company recognizes revenue when title transfers to its customers, which is generally upon the delivery of these products to a customer’s designated location. These deliveries are made in accordance with sales commitments and related sales orders entered into either verbally or in writing with customers. The sales commitments and related sales orders provide quantities, pricing and conditions of sales. In this regard, the Company engages in three basic types of revenue generating transactions:

● As a producer. Sales as a producer consist of sales of the Company’s inventory produced at its plants.

● As a merchant. Sales as a merchant consist of sales to customers through purchases from third-party suppliers in which the Company may or may not obtain physical control of the ethanol, in which shipments are directed from the Company’s suppliers to its terminals or direct to its customers but for which the Company accepts the risk of loss in the transactions.

● As an agent. Sales as an agent consist of sales to customers through purchases from third-party suppliers in which the risks and rewards of inventory ownership remain with third-party suppliers and the Company receives a predetermined service fee under these transactions.

Revenue from sales of third-party ethanol is recorded net of costs when the Company is acting as an agent between a customer and a supplier and gross when the Company is a principal to the transaction. The Company recorded $1,663,000, $1,604,000 and $1,510,000 in net sales when acting as an agent for the years ended December 31, 2017, 2016 and 2015, respectively. Several factors are considered to determine whether the Company is acting as an agent or principal, most notably whether the Company is the primary obligor to the customer and whether the Company has inventory risk and related risk of loss or whether the Company adds meaningful value to the supplier’s product or service. Consideration is also given to whether the Company has latitude in establishing the sales price or has credit risk, or both. When the Company acts as an agent, it recognizes revenue on a net basis or recognizes its predetermined fees and any associated freight, based upon the amount of net revenues retained in excess of amounts paid to suppliers.

The Company records revenues based upon the gross amounts billed to its customers in transactions where the Company acts as a producer or a merchant and obtains title to ethanol and therefore owns the product and any related, unmitigated inventory risk for the ethanol, regardless of whether the Company actually obtains physical control of the product.

Shipping and Handling Costs

Shipping and Handling Costs – Shipping and handling costs are classified as a component of cost of goods sold in the accompanying consolidated statements of operations.

Selling Costs

Selling Costs – Selling costs associated with the Company’s product sales are classified as a component of selling, general and administrative expenses in the accompanying consolidated statements of operations.

Stock-Based Compensation

Stock-Based Compensation – The Company accounts for the cost of employee services received in exchange for the award of equity instruments based on the fair value of the award, determined on the date of grant. The expense is recognized over the period during which an employee is required to provide services in exchange for the award. The Company accounts for forfeitures as they occur. The Company recognizes stock-based compensation expense as a component of selling, general and administrative expenses in the consolidated statements of operations.

Impairment of Long-Lived Assets

Impairment of Long-Lived Assets – The Company assesses the impairment of long-lived assets, including property and equipment, internally developed software and purchased intangibles subject to amortization, when events or changes in circumstances indicate that the fair value of assets could be less than their net book value. In such event, the Company assesses long-lived assets for impairment by first determining the forecasted, undiscounted cash flows the asset group is expected to generate plus the net proceeds expected from the sale of the asset group. If this amount is less than the carrying value of the asset, the Company will then determine the fair value of the asset group. An impairment loss would be recognized when the fair value is less than the related asset group’s net book value, and an impairment expense would be recorded in the amount of the difference. Forecasts of future cash flows are judgments based on the Company’s experience and knowledge of its operations and the industries in which it operates. These forecasts could be significantly affected by future changes in market conditions, the economic environment, including inflation, and purchasing decisions of the Company’s customers.

Deferred Financing Costs

Deferred Financing Costs – Deferred financing costs are costs incurred to obtain debt financing, including all related fees, and are amortized as interest expense over the term of the related financing using the straight-line method, which approximates the interest rate method. Amortization of deferred financing costs was $503,000, $137,000 and $272,000 for the years ended December 31, 2017, 2016 and 2015, respectively. Unamortized deferred financing costs were approximately $1,925,000 and $1,708,000 as of December 31, 2017 and 2016, respectively, and are recorded net of long-term debt in the consolidated balance sheets.

Provision for Income Taxes

Provision for Income Taxes – Income taxes are accounted for under the asset and liability approach, where deferred tax assets and liabilities are determined based on differences between financial reporting and tax basis of assets and liabilities, and are measured using enacted tax rates and laws that are expected to be in effect when the differences reverse. Valuation allowances are established when necessary to reduce deferred tax assets to the amounts expected to be realized.

The Company accounts for uncertainty in income taxes using a two-step approach to recognizing and measuring uncertain tax positions. The first step is to evaluate the tax position for recognition by determining whether it is more likely than not that the position will be sustained on audit, including resolution of related appeals or litigation processes, if any. The second step is to measure the tax benefit as the largest amount which is more than 50% likely of being realized upon ultimate settlement. An uncertain tax position is considered effectively settled on completion of an examination by a taxing authority if certain other conditions are satisfied. Should the Company incur interest and penalties relating to tax uncertainties, such amounts would be classified as a component of interest expense and other income (expense), net, respectively. Deferred tax assets and liabilities are classified as noncurrent in the Company’s consolidated balance sheets.

The Company files a consolidated federal income tax return. This return includes all wholly-owned subsidiaries as well as the Company’s pro-rata share of taxable income from pass-through entities in which the Company owns less than 100%. State tax returns are filed on a consolidated, combined or separate basis depending on the applicable laws relating to the Company and its subsidiaries.

Income (Loss) Per Share

Income (Loss) Per Share – Basic income (loss) per share is computed on the basis of the weighted-average number of shares of common stock outstanding during the period. Preferred dividends are deducted from net income (loss) attributed to Pacific Ethanol, Inc. and are considered in the calculation of income (loss) available to common stockholders in computing basic income (loss) per share. Common stock equivalents to the preferred stock are considered participating securities and are also included in this calculation when dilutive.

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

	Year Ended December 31, 2017
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(34,964	)
Less: Preferred stock dividends		(1,265	)
Basic and Diluted loss per share:
Loss available to common stockholders	$	(36,229	)		42,745	$	(0.85	)

	Year Ended December 31, 2016
	Income Numerator			Shares Denominator		Per-Share Amount
Net income attributed to Pacific Ethanol	$	1,419
Less: Preferred stock dividends		(1,269	)
Less: Allocated to participating securities		(2	)
Basic income per share:
Income available to common stockholders	$	148			42,182	$	0.00
Add: Options		—			69
Diluted income per share:
Income available to common stockholders	$	148			42,251	$	0.00

	Year Ended December 31, 2015
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(18,786	)
Less: Preferred stock dividends		(1,265	)
Basic and Diluted loss per share:
Loss available to common stockholders	$	(20,051	)		33,173	$	(0.60	)

There were an aggregate of 719,000, 704,000 and 817,000 potentially dilutive shares from convertible securities outstanding as of December 31, 2017, 2016 and 2015, respectively. These convertible securities were not considered in calculating diluted income (loss) per common share for the years ended December 31, 2017, 2016 and 2015 as their effect would be anti-dilutive.

Financial Instruments

Financial Instruments – The carrying values of cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities 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.

Employment-related Benefits

Employment-related Benefits – Employment-related benefits associated with pensions and postretirement health care are expensed based on actuarial analysis. The recognition of expense is affected by estimates made by management, such as discount rates used to value certain liabilities, investment rates of return on plan assets, increases in future wage amounts and future health care costs. Discount rates are determined based on a spot yield curve that includes bonds with maturities that match expected benefit payments under the plan.

Estimates and Assumptions

Estimates and Assumptions – The preparation of the consolidated financial statements in conformity with GAAP 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 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.

Subsequent Events

Subsequent Events – Management evaluates, as of each reporting period, events or transactions that occur after the balance sheet date through the date that the financial statements are issued for either disclosure or adjustment to the consolidated financial results.

Reclassifications

Reclassifications – Certain prior year amounts have been reclassified to conform to the current presentation, including the classification of cash collateral balances held with commodity brokers and the classification of external selling costs with respect to the Company’s co-product sales. Cash collateral balances of $4,331,000 as of December 31, 2016 were reclassified from cash and cash equivalents to other current assets on the consolidated balance sheet. External selling costs for the years ended December 31, 2016 and 2015 of $2,526,000 and $2,956,000, respectively, were reclassified from cost of goods sold to selling, general and administrative expenses on the consolidated statements of operations. Such reclassifications had no effect on the consolidated net income (loss), working capital or stockholder’s equity reported in the consolidated statements of operations and consolidated balance sheets.

Recent Accounting Pronouncements

Recent Accounting Pronouncements – In May 2014, the FASB issued new guidance on the recognition of revenue (“ASC 606”). 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 adopted ASC 606 on January 1, 2018. The Company has completed its evaluation of the new requirements under ASC 606 on each of its major revenue types. The Company’s 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, however, will expand certain disclosures of its revenue streams. The Company will adopt the new guidance using the modified retrospective transition method.

In February 2016, the 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, 2018, including interim periods within those fiscal years. The Company expects that upon adoption of this accounting standard, right of use assets and lease obligations will be recognized in its consolidated balance sheets in amounts that will be material.

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.

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ORGANIZATION AND SIGNIFICANT ACCOUNTING POLICIES. (Tables)

12 Months Ended

Dec. 31, 2017

Organization And Significant Accounting Policies Tables

Schedule of concentrations of credit risk major customers

The Company sold ethanol to customers representing 10% or more of the Company’s total net sales, as follows.

	Years Ended December 31,
	2017			2016			2015
Customer A		16	%		17	%		12	%
Customer B		11	%		12	%		15	%
Customer C		6	%		6	%		12	%

Schedule of purchases from external customers

The Company purchased corn from suppliers representing 10% or more of the Company’s total corn purchases, as follows:

	Years Ended December 31,
	2017			2016			2015
Supplier A		14	%		13	%		19	%
Supplier B		13	%		4	%		—	%
Supplier C		10	%		8	%		9	%
Supplier D		9	%		13	%		13	%

Schedule of inventory

Inventory balances consisted of the following (in thousands): 

	December 31,
	2017		2016
Finished goods	$	35,652	$	33,773
Work in progress		8,807		7,092
Raw materials		7,601		6,571
Low-carbon and RIN credits		7,952		10,926
Other		1,538		1,708
Total	$	61,550	$	60,070

Schedule of property and equipment useful lives

Depreciation is computed using the straight-line method over the following estimated useful lives:

Buildings	40 years
Facilities and plant equipment	10 – 25 years
Other equipment, vehicles and furniture	5 – 10 years

Schedule of earnings per share

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

	Year Ended December 31, 2017
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(34,964	)
Less: Preferred stock dividends		(1,265	)
Basic and Diluted loss per share:
Loss available to common stockholders	$	(36,229	)		42,745	$	(0.85	)

	Year Ended December 31, 2016
	Income Numerator			Shares Denominator		Per-Share Amount
Net income attributed to Pacific Ethanol	$	1,419
Less: Preferred stock dividends		(1,269	)
Less: Allocated to participating securities		(2	)
Basic income per share:
Income available to common stockholders	$	148			42,182	$	0.00
Add: Options		—			69
Diluted income per share:
Income available to common stockholders	$	148			42,251	$	0.00

	Year Ended December 31, 2015
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(18,786	)
Less: Preferred stock dividends		(1,265	)
Basic and Diluted loss per share:
Loss available to common stockholders	$	(20,051	)		33,173	$	(0.60	)

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PACIFIC ETHANOL PLANTS. (Tables)

12 Months Ended

Dec. 31, 2017

Pacific Aurora [Member]

Schedule of purchase price allocation

The carrying values and classification of assets and liabilities of Pacific Aurora as of December 31, 2016 were as follows (in thousands):

Cash and equivalents	$	1,453
Accounts receivable		16,804
Inventories		3,837
Other current assets		77
Total current assets		22,171
Property and equipment		115,759
Other assets		1,387
Total assets	$	139,317
Accounts payable and accrued liabilities	$	20,152
Other current liabilities		2,045
Long-term debt outstanding, net		621
Total liabilities	$	22,818

PE Central [Member]

Schedule of purchase price allocation

The purchase price consideration allocation is as follows (in thousands):

Cash and equivalents	$	18,756
Accounts receivable		10,430
Inventories		29,483
Other current assets		8,304
Total current assets		66,973
Property and equipment		312,781
Net deferred tax assets		12,159
Other assets		750
Total assets acquired	$	392,663
Accounts payable and accrued liabilities	$	27,780
Long-term debt - revolvers		13,721
Long-term debt - term debt		142,744
Pension plan liabilities		8,518
Other non-current liabilities		25,327
Total liabilities assumed	$	218,090
Net assets acquired	$	174,573

Schedule of pro forma allocation

The following table presents unaudited pro forma financial information for the year ended December 31, 2015, assuming the acquisition occurred on January 1, 2014 (in thousands except per share data).

Net sales – pro forma	$	1,484,676
Cost of goods sold – pro forma	$	1,469,512
Selling, general and administrative expenses – pro forma	$	34,735
Net loss – pro forma	$	(34,136	)
Diluted net loss per share – pro forma	$	(0.81	)
Diluted weighted-average shares – pro forma		42,053

ICP [Member]

Schedule of purchase price allocation

The Company has recognized the following allocation of the purchase price at fair values. No intangible assets or liabilities have been recognized due to ICP’s contracts being materially close to market prices. The Company’s purchase price consideration allocation is as follows (in thousands):

Cash and equivalents	$	426
Accounts receivable		11,636
Inventories		9,227
Other current assets		1,560
Total current assets		22,849
Property and equipment		61,128
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 pro forma allocation

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

	Years Ended December 31,
	2017			2016
Revenues – pro forma	$	1,710,317		$	1,802,159
Consolidated net income (loss) – pro forma	$	(42,589	)	$	8,329
Diluted net income (loss) per share – pro forma	$	(0.95	)	$	0.16
Diluted weighted-average shares – pro forma		42,745			42,251

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SEGMENTS. (Tables)

12 Months Ended

Dec. 31, 2017

Segment Reporting [Abstract]

Schedule of financial date for operating segments

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

	Years Ended December 31,
	2017			2016			2015
Net Sales
Production:
Net sales to external customers	$	1,102,722		$	1,045,807		$	710,201
Intersegment net sales		1,898			1,169			—
Total production segment net sales		1,104,620			1,046,976			710,201
Marketing and distribution:
Net sales to external customers		529,533			578,951			480,975
Intersegment net sales		8,464			8,029			5,262
Total marketing and distribution net sales		537,997			586,980			486,237
Intersegment eliminations		(10,362	)		(9,198	)		(5,262	)
Net sales as reported	$	1,632,255		$	1,624,758		$	1,191,176
Cost of goods sold:
Production	$	1,098,977		$	1,015,655		$	716,877
Marketing and distribution		535,032			575,921			476,410
Intersegment eliminations		(7,685	)		(21,176	)		(12,477	)
Cost of goods sold as reported	$	1,626,324		$	1,570,400		$	1,180,810
Income (loss) before provision for income taxes:
Production	$	(27,458	)	$	(6,882	)	$	(32,723	)
Marketing and distribution		(2,463	)		4,517			3,200
Corporate activities		(8,474	)		2,910			616
	$	(38,395	)	$	545		$	(28,907	)
Depreciation and amortization:
Production	$	37,637		$	34,528		$	23,091
Marketing and distribution		—			3			151
Corporate activities		1,014			910			390
	$	38,651		$	35,441		$	23,632
Interest expense:
Production	$	5,887		$	20,794		$	11,969
Marketing and distribution		1,271			1,404			625
Corporate activities		5,780			208			—
	$	12,938		$	22,406		$	12,594

Schedule of assets by operating segments

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

	December 31,
	2017		2016
Total assets:
Production	$	583,696	$	542,688
Marketing and distribution		127,242		146,356
Corporate assets		9,358		19,194
	$	720,296	$	708,238

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PROPERTY AND EQUIPMENT. (Tables)

12 Months Ended

Dec. 31, 2017

Property, Plant and Equipment [Abstract]

Schedule of property and equipment

Property and equipment consisted of the following (in thousands):

	December 31,
	2017			2016
Facilities and plant equipment	$	601,156		$	530,735
Land		8,970			7,771
Other equipment, vehicles and furniture		10,189			9,714
Construction in progress		38,041			29,393
		658,356			577,613
Accumulated depreciation		(150,004	)		(112,423	)
	$	508,352		$	465,190

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DERIVATIVES. (Tables)

12 Months Ended

Dec. 31, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of derivatives not designated as hedging instruments

The classification and amounts of the Company’s derivatives not designated as hedging instruments, and related cash collateral balances, are as follows (in thousands): 

	As of December 31, 2017
	Assets			Liabilities
Type of Instrument	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Cash collateral balance	Other current assets	$	3,813
Commodity contracts	Derivative assets	$	998	Derivative liabilities	$	2,307

	As of December 31, 2016
	Assets			Liabilities
Type of Instrument	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Cash collateral balance	Other current assets	$	4,331
Commodity contracts	Derivative assets	$	978	Derivative liabilities	$	4,115

Schedule of recognized gains (losses) on derivatives

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)
		For the Years Ended December 31,
Type of Instrument	Statements of Operations Location	2017			2016		2015
Commodity contracts	Cost of goods sold	$	(4,165	)	$	1,386	$	(338	)
		$	(4,165	)	$	1,386	$	(338	)

		Unrealized Gains (Losses)
		For the Years Ended December 31,
Type of Instrument	Statements of Operations Location	2017		2016			2015
Commodity contracts	Cost of goods sold	$	2,088	$	(3,370	)	$	(204	)
		$	2,088	$	(3,370	)	$	(204	)

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DEBT. (Tables)

12 Months Ended

Dec. 31, 2017

Debt Disclosure [Abstract]

Schedule of long term debt

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

	December 31, 2017			December 31, 2016
Kinergy line of credit	$	49,477		$	49,862
Pekin term loan		53,500			64,000
Pekin revolving loan		32,000			32,000
ICP term loan		22,500			—
ICP revolving loan		18,000			—
Pacific Aurora line of credit		—			1,000
Parent notes payable		68,948			55,000
		244,425			201,862
Less unamortized debt discount		(1,409	)		(1,626	)
Less unamortized debt financing costs		(1,925	)		(1,708	)
Less short-term portion		(20,000	)		(10,500	)
Long-term debt	$	221,091		$	188,028

Schedule of maturities of long-term debt

The Company’s long-term debt matures as follows (in thousands):

December 31:
	2018	$	20,000
	2019		88,948
	2020		20,000
	2021		16,000
	2022		99,477
		$	244,425

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PENSION PLANS. (Tables)

12 Months Ended

Dec. 31, 2017

Retirement Plan [Member]

Schedule of defined contribution plan schedule

Information related to the Retirement Plan as of and for the years ended December 31, 2017, 2016 and 2015 is presented below (dollars in thousands):

	2017			2016			2015
Changes in plan assets:
Fair value of plan assets, beginning	$	12,423		$	12,567		$	13,180
Actual gains (losses)		1,722			523			(298	)
Benefits paid		(665	)		(667	)		(315	)
Company contributions		478			—			—
Participant contributions		—			—			—
Fair value of plan assets, ending	$	13,958		$	12,423		$	12,567
Less: projected accumulated benefit obligation	$	19,658		$	18,455		$	16,552
Funded status, (underfunded)/overfunded	$	(5,700	)	$	(6,032	)	$	(3,985	)
Amounts recognized in the consolidated balance sheets:
Other liabilities	$	(5,700	)	$	(6,032	)	$	(3,985	)
Accumulated other comprehensive loss (income)	$	726		$	1,047		$	(885	)
Components of net periodic benefit costs are as follows:
Service cost	$	391		$	223		$	211
Interest cost		750			686			338
Expected return on plan assets		(674	)		(794	)		(500	)
Net periodic benefit cost	$	467		$	115		$	49
Loss (gain) recognized in other comprehensive income (expense)	$	(321	)	$	1,932		$	(885	)
Assumptions used in computation benefit obligations:
Discount rate		3.60	%		4.15	%		4.23	%
Expected long-term return on plan assets		6.00	%		6.75	%		7.75	%
Rate of compensation increase		—			—			—

Schedule of expected benefit payments

The following table summarizes the expected benefit payments for the Company’s plan for each of the next five fiscal years and in the aggregate for the five fiscal years thereafter (in thousands):

December 31:
	2018	$	730
	2019		740
	2020		780
	2021		790
	2022		830
	2023-27		4,820
		$	8,690

Postretirement Plan [Member]

Schedule of defined contribution plan schedule

Information related to the Postretirement Plan as of December 31, 2017 and 2016 is presented below (dollars in thousands):

	2017			2016
Amounts at the end of the year:
Accumulated/projected benefit obligation	$	5,565		$	5,371
Fair value of plan assets		—			—
Funded status, (underfunded)/overfunded	$	(5,565	)	$	(5,371	)
Amounts recognized in the consolidated balance sheets:
Accrued liabilities	$	(240	)	$	(310	)
Other liabilities	$	(5,325	)	$	(5,061	)
Accumulated other comprehensive loss	$	1,508		$	1,573

	Years Ended December 31,
	2017			2016			2015
Amounts recognized in the plan for the year:
Company contributions	$	157		$	163		$	20
Participant contributions	$	22		$	22		$	15
Benefits paid	$	(179	)	$	(184	)	$	(35	)
Components of net periodic benefit costs are as follows:
Service cost	$	84		$	48		$	32
Interest cost		198			139			65
Amortization of prior service costs		134			—			—
Net periodic benefit cost	$	416		$	187		$	97
Loss (gain) recognized in other comprehensive income	$	(65	)	$	1,728		$	(155	)
Discount rate used in computation of benefit obligations		3.80	%		3.95	%		3.67	%

Schedule of expected benefit payments

The following table summarizes the expected benefit payments for the Company’s plan for each of the next five fiscal years and in the aggregate for the five fiscal years thereafter (in thousands):

December 31:
	2018	$	240
	2019		270
	2020		300
	2021		340
	2022		330
	2023-27		2,120
		$	3,600

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INCOME TAXES. (Tables)

12 Months Ended

Dec. 31, 2017

Income Tax Disclosure [Abstract]

Schedule of provision for income taxes

The Company recorded a provision (benefit) for income taxes as follows (in thousands):

	Years Ended December 31,
	2017			2016			2015
Current provision (benefit)	$	(490	)	$	141		$	(8,011	)
Deferred provision (benefit)		169			(1,122	)		(2,023	)
Total	$	(321	)	$	(981	)	$	(10,034	)

Schedule of reconciliation of effective tax rate

A reconciliation of the differences between the United States statutory federal income tax rate and the effective tax rate as provided in the consolidated statements of operations is as follows:

	Years Ended December 31,
	2017			2016			2015
Statutory rate		35.0	%		35.0	%		35.0	%
State income taxes, net of federal benefit		4.0			6.4			9.2
Change in valuation allowance		(34.5	)		(298.8	)		(4.2	)
Impact of Federal tax rate change on deferreds		(28.4	)		—			—
Impact of Federal tax rate change on valuation allowance		29.4			—			—
Fair value adjustments and warrant inducements		0.4			37.2			2.0
Noncontrolling interests		(3.2	)		—			—
Domestic production gross receipts deduction		—			—			(2.9	)
Section 382 reduction to loss carryover		—			—			0.1
Stock compensation		(0.1	)		58.8			(0.8	)
Non-deductible items		(0.2	)		8.9			(0.5	)
Other		(1.6	)		(27.5	)		(3.2	)
Effective rate		0.8	%		(180.0	)%		34.7	%

Schedule of components of deferred income taxes

Deferred income taxes are provided using the asset and liability method to reflect temporary differences between the financial statement carrying amounts and the tax bases of assets and liabilities using presently enacted tax rates and laws. The components of deferred income taxes included in the consolidated balance sheets were as follows (in thousands):

	December 31,
	2017			2016
Deferred tax assets:
Net operating loss carryforwards	$	40,989		$	45,709
R&D and AMT credits		1,797			2,465
Railcar contracts		1,415			3,348
Stock-based compensation		738			946
Allowance for doubtful accounts and other assets		637			856
Derivatives		267			1,228
Pension liability		2,939			2,204
Other		2,097			4,316
Total deferred tax assets		50,879			61,072
Deferred tax liabilities:
Property and equipment		(25,194	)		(45,757	)
Intangibles		(749	)		(1,091	)
Other		(521	)		(1,593	)
Total deferred tax liabilities		(26,464	)		(48,441	)
Valuation allowance		(24,639	)		(12,683	)
Net deferred tax liabilities, included in other liabilities	$	(224	)	$	(52	)

Schedule of net operating loss carryforwards

These net operating loss carryforwards expire as follows (in thousands):

Tax Years	Federal		State
2018–2022	$	—	$	—
2023–2027		13,038		2,945
2028–2032		22,025		65,921
2033–2036		119,526		80,055
	$	154,589	$	148,921

Certain of these net operating losses are not immediately available, but become available to be utilized in each of the years ended December 31, as follows (in thousands):

Year	Federal		State
2017	$	59,675	$	82,892
2018		6,441		5,372
2019		6,374		5,345
2020		6,308		5,318
2021		6,308		5,318
Thereafter		69,483		44,676
	$	154,589	$	148,921

Schedule of income tax in the United States jurisdiction and various state jurisdictions

These jurisdictions, along with the years still open to audit under the applicable statutes of limitation, are as follows:

Jurisdiction	Tax Years
Federal	2014 – 2016
Arizona	2014 – 2016
California	2013 – 2016
Colorado	2013 – 2016
Idaho	2014 – 2016
Illinois	2014 – 2016
Indiana	2014 – 2016
Iowa	2014 – 2016
Kansas	2014 – 2016
Minnesota	2014 – 2016
Missouri	2014 – 2016
Nebraska	2014 – 2016
Oklahoma	2014 – 2016
Oregon	2014 – 2016
Texas	2013 – 2016

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COMMON STOCK AND WARRANTS. (Tables)

12 Months Ended

Dec. 31, 2017

Stockholders' Equity Note [Abstract]

Schedule of warrant activity

The following table summarizes warrant activity for the years ended December 31, 2017, 2016 and 2015 (number of shares in thousands):

	Number of Shares			Price per Share	Weighted Average Exercise Price
Balance at December 31, 2014		856		$6.09 – $735.00	$	36.55
Warrants exercised		(42	)	$8.85	$	8.85
Warrants expired		(432	)	$8.85	$	8.85
Balance at December 31, 2015		382		$6.09 – $735.00	$	70.87
Warrants exercised		(138	)	$8.43	$	8.43
Balance at December 31, 2016		244		$6.09 – $735.00	$	106.72
Warrants exercised		(191	)	$6.09	$	6.09
Warrants expired		(49	)	$6.09 – $735.00	$	444.00
Balance at December 31, 2017		4		$735.00	$	735.00

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STOCK BASED COMPENSATION. (Tables)

12 Months Ended

Dec. 31, 2017

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Schedule of option activity

Summaries of the status of Company’s stock option plans as of December 31, 2017 and 2016 and of changes in options outstanding under the Company’s plans during those years are as follows (number of shares in thousands):

	Years Ended December 31,
	2017					2016
	Number of Shares			Weighted Average Exercise Price		Number of Shares		Weighted Average Exercise Price
Outstanding at beginning of year		240		$	4.18		240	$	4.18
Exercised		(10	)		3.74		—		—
Outstanding at end of year		230		$	4.18		240	$	4.18
Options exercisable at end of year		230		$	4.18		240	$	4.18

Schedule of stock options by exercise price range

Stock options outstanding as of December 31, 2017 were as follows (number of shares in thousands): 

		Options Outstanding				Options Exercisable
	Range of Exercise Prices	Number  Outstanding	Weighted Average Remaining Contractual Life (yrs.)		Weighted Average  Exercise  Price	Number Exercisable		Weighted  Average   Exercise  Price
$	3.74	219	5.47	$	3.74	219	$	3.74
$	12.90	11	3.59	$	12.90	11	$	12.90

Schedule of unvested restricted stock activity

The Company granted to certain employees and directors shares of restricted stock under its 2006 and 2016 Stock Incentive Plans. A summary of unvested restricted stock activity is as follows (shares in thousands):

	Number of Shares			Weighted Average Grant Date  Fair Value Per Share
Unvested at December 31, 2014		390		$	8.71
Issued		307		$	10.16
Vested		(220	)	$	7.94
Canceled		(14	)	$	10.08
Unvested at December 31, 2015		463		$	10.00
Issued		742		$	5.24
Vested		(250	)	$	9.01
Canceled		(25	)	$	6.24
Unvested at December 31, 2016		930		$	6.57
Issued		664		$	6.65
Vested		(480	)	$	7.30
Canceled		(37	)	$	6.08
Unvested at December 31, 2017		1,077		$	6.31

Schedule of stock-based compensation expense

Stock-based compensation expense related to employee and non-employee restricted stock and option grants recognized in selling, general and administrative expenses, were as follows (in thousands):\

	Years Ended December 31,
	2017		2016		2015
Employees	$	3,303	$	2,173	$	1,694
Non-employees		525		443		325
Total stock-based compensation expense	$	3,828	$	2,616	$	2,019

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COMMITMENTS AND CONTINGENCIES. (Tables)

12 Months Ended

Dec. 31, 2017

Commitments and Contingencies Disclosure [Abstract]

Schedule of future minimum lease payments - Capital and Operating Leases

Future minimum lease payments required by non-cancelable leases in effect at December 31, 2017 were as follows (in thousands):

Years Ended December 31,	Capital Leases			Operating Leases
2018	$	613		$	11,841
2019		45			9,236
2020		45			7,042
2021		34			4,074
2022		—			3,894
Thereafter		—			5,530
Total minimum payments		737		$	41,617
Amount representing interest		(22	)
Obligations under capital leases		715
Obligations due within one year		(592	)
Long-term obligations under capital leases	$	123

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FAIR VALUE MEASUREMENTS. (Tables)

12 Months Ended

Dec. 31, 2017

Fair Value Disclosures [Abstract]

Schedule of fair value measurements

											Benefit Plan
	Fair										Percentage
	Value			Level 1			Level 2		Level 3		Allocation
Assets:
Derivative financial instruments(1)	$	998		$	998		$	—	$	—
Defined benefit plan assets(2) (pooled separate accounts):
Large U.S. Equity(3)		3,748			—			3,748		—		27	%
Small/Mid U.S. Equity(4)		2,018			—			2,018		—		14	%
International Equity(5)		2,528			—			2,528		—		18	%
Fixed Income(6)		5,664			—			5,664		—		41	%
	$	14,956		$	998		$	13,958	$	—
Liabilities:
Derivative financial instruments(7)	$	(2,307	)	$	(2,307	)	$	—	$	—

The following table summarizes recurring fair value measurements by level at December 31, 2016 (in thousands):

												Benefit Plan
	Fair											Percentage
	Value			Level 1			Level 2		Level 3			Allocation
Assets:
Derivative financial instruments(1)	$	978		$	978		$	—	$	—
Defined benefit plan assets(2) (pooled separate accounts):
Large U.S. Equity(3)		3,134			—			3,134		—			25	%
Small/Mid U.S. Equity(4)		1,802			—			1,802		—			15	%
International Equity(5)		2,006			—			2,006		—			16	%
Fixed Income(6)		5,481			—			5,481		—			44	%
	$	13,401		$	978		$	12,423	$	—
Liabilities:
Warrants(8)	$	(651	)	$	—		$	—	$	(651	)
Derivative financial instruments(7)		(4,115	)		(4,115	)		—		—
	$	(4,766	)	$	(4,115	)	$	—	$	(651	)

(1) Included in derivative assets in the consolidated balance sheets.

(2) See Note 9 for accounting discussion.

(3) This category includes investments in funds comprised of equity securities of large U.S. companies. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(4) This category includes investments in funds comprised of equity securities of small- and medium-sized U.S. companies. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(5) This category includes investments in funds comprised of equity securities of foreign companies including emerging markets. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(6) This category includes investments in funds comprised of U.S. and foreign investment-grade fixed income securities, high-yield fixed income securities that are rated below investment-grade, U.S. treasury securities, mortgage-backed securities, and other asset-backed securities. The funds are valued using the net asset value method in which an average of the market prices for the underlying investments is used to value the fund.

(7) Included in derivative liabilities in the consolidated balance sheets.

(8) Included in warrant liabilities at fair value in the consolidated balance sheets.

Schedule of significant assumptions

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

Schedule of level 3 fair value schedule

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

	Warrants
Balance, December 31, 2014	$	1,986
Exercises of warrants		(72	)
Expiration of warrants		(527	)
Adjustments to fair value for the period		(1,114	)
Balance, December 31, 2015	$	273
Exercises of warrants		(179	)
Adjustments to fair value for the period		557
Balance, December 31, 2016	$	651
Exercises of warrants		(178	)
Adjustments to fair value for the period		(473	)
Balance, December 31, 2017	$	—

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PARENT COMPANY FINANCIALS. (Tables)

12 Months Ended

Dec. 31, 2017

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

Schedule of balance sheets - parent company

Parent company financial statements for the periods covered in this report are set forth below.

	December 31,
	2017			2016
ASSETS
Current Assets:
Cash and cash equivalents	$	5,314		$	11,060
Receivables from subsidiaries		3,138			7,203
Other current assets		1,631			6,442
Total current assets		10,083			24,705
Property and equipment, net		1,071			1,433
Other Assets:
Investments in subsidiaries		359,680			363,401
Pacific Ethanol West plant receivable		58,766			58,766
Other assets		1,565			1,110
Total other assets		420,011			423,277
Total Assets	$	431,165		$	449,415
Current Liabilities:
Accounts payable and accrued liabilities	$	2,218		$	1,758
Payable to subsidiaries		625			1,568
Accrued PE Op Co. purchase		3,828			3,828
Other current liabilities		245			184
Total current liabilities		6,916			7,338
Long-term debt, net		67,530			53,360
Warrant liabilities at fair value		—			651
Deferred tax liabilities		224			52
Other liabilities		56			124
Total Liabilities		74,726			61,525
Stockholders’ Equity:
Preferred stock		1			1
Common and non-voting common stock		44			44
Additional paid-in capital		927,090			922,698
Accumulated other comprehensive loss		(2,234	)		(2,620	)
Accumulated deficit		(568,462	)		(532,233	)
Total Pacific Ethanol, Inc. stockholders’ equity		356,439			387,890
Total Liabilities and Stockholders’ Equity	$	431,165		$	449,415

Schedule of statements of operations parent company

	Years Ended December 31,
	2017			2016			2015
Management fees from subsidiaries	$	11,904		$	12,968		$	9,857
Selling, general and administrative expenses		18,185			14,491			14,336
Asset impairment		—			—			1,970
Loss from operations		(6,281	)		(1,523	)		(6,449	)
Fair value adjustments		473			(557	)		1,641
Interest income		4,793			5,964			5,739
Interest expense		(5,829	)		(240	)		(27	)
Other income (expense), net		(95	)		1,931			—
Income (loss) before provision for income taxes		(6,939	)		5,575			904
Provision (benefit) for income taxes		(321	)		(981	)		(10,034	)
Income (loss) before equity in earnings of subsidiaries		(6,618	)		6,556			10,938
Equity in losses of subsidiaries		(28,346	)		(5,137	)		(29,724	)
Consolidated net income (loss)	$	(34,964	)	$	1,419		$	(18,786	)

Schedule of statements of cash flows parent company

	For the Years Ended December 31,
	2017			2016			2015
Operating Activities:
Net income (loss)	$	(34,964	)	$	1,419		$	(18,786	)
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Equity in losses of subsidiaries		28,346			5,137			29,724
Dividends from subsidiaries		3,500			—			—
Depreciation and amortization		830			727			390
Fair value adjustments		(473	)		557			(1,641	)
Asset impairment		—			—			1,970
Deferred income taxes		169			(1,122	)		(14,260	)
Amortization of debt discounts		636			10			—
Changes in operating assets and liabilities:
Accounts receivables		4,065			7,302			(5,958	)
Other assets		4,356			4,647			(4,139	)
Accounts payable and accrued expenses		3,859			(3,741	)		604
Accounts payable with subsidiaries		(943	)		(9,385	)		11,179
Net cash provided by (used in) operating activities	$	9,381		$	5,551		$	(917	)
Investing Activities:
Additions to property and equipment	$	(468	)	$	(465	)	$	(1,483	)
Investments in subsidiaries		(28,126	)		(50,886	)		—
Purchase of PE OP Co. debt		—			(17,003	)		—
Net cash used in investing activities	$	(28,594	)	$	(68,354	)	$	(1,483	)
Financing Activities:
Proceeds from issuances of senior notes	$	13,530		$	53,350		$	—
Proceeds from warrant stock option exercises		1,202			1,164			368
Preferred stock dividend payments		(1,265	)		(1,269	)		(1,265	)
Net cash provided by (used in) financing activities	$	13,467		$	53,245		$	(897	)
Net decrease in cash and cash equivalents		(5,746	)		(9,558	)		(3,297	)
Cash and cash equivalents at beginning of period		11,060			20,618			23,915
Cash and cash equivalents at end of period	$	5,314		$	11,060		$	20,618

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QUARTERLY FINANCIAL DATA. (Tables)

12 Months Ended

Dec. 31, 2017

Quarterly Financial Information Disclosure [Abstract]

Schedule of quarterly financial data

The Company’s quarterly results of operations for the years ended December 31, 2017 and 2016 are as follows (in thousands). Certain of these calculations have been revised from the calculations previously reported to reflect the participating securities.

	First Quarter			Second Quarter			Third Quarter			Fourth Quarter
December 31, 2017:
Net sales	$	386,340		$	405,202		$	445,442		$	395,271
Gross profit (loss)	$	(5,773	)	$	1,653		$	12,065		$	(2,014	)
Income (loss) from operations	$	(11,223	)	$	(7,109	)	$	3,345		$	(10,598	)
Net loss attributed to Pacific Ethanol, Inc.	$	(12,636	)	$	(8,841	)	$	(202	)	$	(13,285	)
Preferred stock dividends	$	(312	)	$	(315	)	$	(319	)	$	(319	)
Net loss available to common stockholders	$	(12,948	)	$	(9,156	)	$	(521	)	$	(13,604	)
Basic and diluted loss per common share	$	(0.31	)	$	(0.22	)	$	(0.01	)	$	(0.32	)
	First Quarter			Second Quarter			Third Quarter			Fourth Quarter
December 31, 2016:
Net sales	$	342,373		$	422,860		$	417,806		$	441,719
Gross profit	$	1,668		$	18,355		$	7,021		$	27,314
Income (loss) from operations	$	(7,248	)	$	11,556		$	393		$	18,808
Net income (loss) attributed to Pacific Ethanol, Inc.	$	(13,226	)	$	5,086		$	(3,518	)	$	13,077
Preferred stock dividends	$	(315	)	$	(315	)	$	(319	)	$	(320	)
Income allocated to participating securities	$	—		$	(71	)	$	—		$	(189	)
Net income (loss) available to common stockholders	$	(13,541	)	$	4,700		$	(3,837	)	$	12,569
Basic and diluted income (loss) per common share	$	(0.32	)	$	0.11		$	(0.09	)	$	0.30

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ORGANIZATION AND SIGNIFICANT ACCOUNTING POLICIES. (Details) - Sales [Member]	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Customer A [Member]
Concentration risk percentage	16.00%	17.00%	12.00%
Customer C [Member]
Concentration risk percentage	6.00%	6.00%	12.00%
Customer B [Member]
Concentration risk percentage	11.00%	12.00%	15.00%

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ORGANIZATION AND SIGNIFICANT ACCOUNTING POLICIES. (Details 1) - Purchases [Member]	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Supplier C [Memebr]
Concentration percentage	10.00%	8.00%	9.00%
Supplier B [Member]
Concentration percentage	13.00%	4.00%
Supplier A [Member]
Concentration percentage	14.00%	13.00%	19.00%
Supplier D [Memebr]
Concentration percentage	9.00%	13.00%	13.00%

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ORGANIZATION AND SIGNIFICANT ACCOUNTING POLICIES. (Details 2) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Finished goods	$ 35,652	$ 33,773
Work in progress	8,807	7,092
Raw materials	7,601	6,571
Low-carbon and RIN credits	7,952	10,926
Other	1,538	1,708
Total inventories	$ 61,550	$ 60,070

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ORGANIZATION AND SIGNIFICANT ACCOUNTING POLICIES. (Details 3)	12 Months Ended
	Dec. 31, 2017
Building [Member]
Estimated useful lives	P40Y
Facilities and plant equipment [Member] | Minimum [Member]
Estimated useful lives	P10Y
Facilities and plant equipment [Member] | Maximum [Member]
Estimated useful lives	P25Y
Other equipment, vehicles and furniture [Member] | Minimum [Member]
Estimated useful lives	P5Y
Other equipment, vehicles and furniture [Member] | Maximum [Member]
Estimated useful lives	P10Y

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ORGANIZATION AND SIGNIFICANT ACCOUNTING POLICIES. (Details 4) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Loss Numerator
Net income (loss) attributed to Pacific Ethanol, Inc.	$ (13,285)	$ (202)	$ (8,841)	$ (12,636)	$ 13,077	$ (3,518)	$ 5,086	$ (13,226)	$ (34,964)	$ 1,419	$ (18,786)
Less: Preferred stock dividends	(319)	(319)	(315)	(312)	(320)	(319)	(315)	(315)	(1,265)	(1,269)	(1,265)
Less: Allocated to participating securities					(189)	0	(71)	0		(2)
Basic income per share:
Income available to common stockholders, basic	$ (13,604)	$ (521)	$ (9,156)	$ (12,948)	$ 12,569	$ (3,837)	$ 4,700	$ (13,541)	$ (36,229)	148	$ (20,051)
Diluted income per share:
Income available to common stockholders, diluted										$ 148
Shares Denominator
Shares available to common stockholders - basic									42,745	42,182	33,173
Incremental shares - Options										69
Shares available to common stockholders - diluted									42,745	42,251	33,173
Per-Share Amount
Per-Share amount - basic									$ (0.85)	$ 0.00	$ (0.60)
Per-Shares amount - diluted									$ (0.85)	$ 0.00	$ (0.6)

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ORGANIZATION AND SIGNIFICANT ACCOUNTING POLICIES. (Details Narrative) $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($) Number shares	Dec. 31, 2016 USD ($) shares	Dec. 31, 2015 USD ($) shares	Dec. 15, 2016	Jul. 31, 2015 Number
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 3.0 million tons of co-products
Accounts receivable used as collateral	$ 64,501	$ 64,853
Allowance for doubtful accounts	19	331
Bad debt recovery	(5)	(306)	$ 354
Bad debt expense	5	306
Accounts receivable	$ 80,344	86,275
Employees covered by collective bargaining agreement	32.00%
Net inventory valuation adjustment	$ 2,700
Net sales when company acting as an agent	1,663	1,604	1,510
Amortization of deferred financing costs	503	137	$ 272
Unamortized deferred financing costs	$ 1,925	$ 1,708
Potentially dilutive shares from convertible securities outstanding | shares	719,000	704,000	817,000
Cash collateral balances		$ 4,331
Selling, General and Administrative Expenses [Member]
External selling costs		2,526	$ 2,956
Customer A, B and C [Member]
Accounts receivable	$ 21,584	$ 21,274
Concentration risk percentage	27.00%	25.00%
ACEC [Member]
Noncontrolling interest owned	26.07%	26.07%
Pacific Ethanol Central Plants [Member]
Number of ethanol plants | Number	4
Midwestern Ethanol Plants [Member]
Number of ethanol plants | Number					4
Pacific Aurora [Member]
Ownership interest	73.93%	73.93%		100.00%
Pacific Aurora [Member] | ACEC [Member]
Ownership interest	26.07%	26.07%

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PACIFIC ETHANOL PLANTS. (Details) - USD ($) $ in Thousands	Jul. 03, 2017	Dec. 31, 2016	Jul. 01, 2015	Jun. 30, 2015
ICP [Member]
Cash and equivalents	$ 426
Accounts receivable	11,636
Inventories	9,227
Other current assets	1,560
Total current assets	22,849
Property and equipment	61,128
Other assets	328
Total assets acquired	84,305
Accounts payable and accrued liabilities	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
Pacific Aurora [Member]
Cash and equivalents		$ 1,453
Accounts receivable		16,804
Inventories		3,837
Other current assets		77
Total current assets		22,171
Property and equipment		115,759
Other assets		1,387
Total assets acquired		139,317
Accounts payable and accrued liabilities		20,152
Other current liabilities		2,045
Long-term debt - term debt		621
Total liabilities assumed		$ 22,818
PE Central [Member]
Cash and equivalents				$ 18,756
Accounts receivable			$ 10,800	10,430
Inventories				29,483
Other current assets				8,304
Total current assets				66,973
Property and equipment				312,781
Net deferred tax assets				12,159
Other assets				750
Total assets acquired				392,663
Accounts payable and accrued liabilities				27,780
Long-term debt - revolvers				13,721
Long-term debt - term debt				142,744
Pension plan liabilties				8,518
Other non-current liabilities				25,327
Total liabilities assumed				218,090
Net assets acquired				$ 174,573

XML

PACIFIC ETHANOL PLANTS. (Details 1) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
ICP [Member]
Net sales - pro forma	$ 1,710,317	$ 1,802,159
Consolidated net income (loss) - pro forma	$ (42,589)	$ 8,329
Diluted net income (loss) per share - pro forma	$ (0.95)	$ 0.16
Diluted weighted-average shares - pro forma	$ 42,745	$ 42,251
PE Central [Member]
Net sales - pro forma			$ 1,484,676
Cost of goods sold - pro forma			1,469,512
Selling, general and administrative expenses - pro forma			34,735
Consolidated net income (loss) - pro forma			$ (34,136)
Diluted net income (loss) per share - pro forma			$ (0.81)
Diluted weighted-average shares - pro forma			$ 42,053

XML

PACIFIC ETHANOL PLANTS. (Details Narrative) - USD ($)
$ in Thousands

1 Months Ended

3 Months Ended

6 Months Ended

12 Months Ended

Jul. 03, 2017

Dec. 15, 2016

Jul. 01, 2015

May 31, 2015

Dec. 31, 2017

Sep. 30, 2017

Jun. 30, 2017

Mar. 31, 2017

Dec. 31, 2016

Sep. 30, 2016

Jun. 30, 2016

Mar. 31, 2016

Dec. 31, 2015

Dec. 31, 2017

Dec. 31, 2016

Dec. 31, 2015

Jun. 30, 2015

Apr. 30, 2015

Ethanol production capacity per year

605 million gallons per year

Net Revenue

$ 395,271

$ 445,442

$ 405,202

$ 386,340

$ 441,719

$ 417,806

$ 422,860

$ 342,373

$ 1,632,255

$ 1,624,758

$ 1,191,176

Pre-tax income

(38,395)

545

(28,907)

Gain on settlement

$ 31,516

$ 30,849

26,368

Pacific Aurora [Member]

Equity interest owned

100.00%

73.93%

73.93%

73.93%

73.93%

Cash received in sale of subsidiary

$ 30,000

Description of agreement closed term

(i) PE Central contributed to Pacific Aurora 100% of the equity interests of its wholly-owned subsidiaries, Pacific Ethanol Aurora East, LLC (“AE”) and Pacific Ethanol Aurora West, LLC (“AW”), which owned the Company’s Aurora East and Aurora West ethanol plants, respectively, in exchange for an 88.15% ownership interest in Pacific Aurora, and (ii) ACEC contributed to Pacific Aurora its grain elevator adjacent to the Aurora East and Aurora West properties and related grain handling assets, including the outer rail loop and the real property on which they are located, in exchange for an 11.85% ownership interest in Pacific Aurora.

Ownership interest sold

14.22%

ACEC contribution in assets

$ 16,500

$ 16,500

ACEC additional cash contribution

$ 30,000

30,000

Additional paid in capital for book value and contribution and sale

$ 16,200

Minimum working capital

$ 15,000

Pacific Aurora [Member] | ACEC [Member]

Equity interest owned

26.07%

26.07%

26.07%

26.07%

ICP [Member]

Equity interest owned

100.00%

Cash received in sale of subsidiary

$ 30,000

Stock issued for acquisition, value

$ 46,900

Ethanol production capacity per year

90 million gallon per year

Accounts receivable

$ 11,636

Net Revenue

$ 75,900

Pre-tax income

3,700

Selling, general and administrative expenses

300

PE Central [Member]

Stock issued for acquisition, value

$ 174,600

Accounts receivable

$ 10,800

$ 10,430

Net Revenue

$ 299,000

610,500

$ 650,100

Pre-tax income

16,300

8,400

2,100

Selling, general and administrative expenses

1,400

Percentage of interests auquired

100.00%

Stock issued for acquisition, shares issued

17,800,000

Uncollectible accounts receivable from acquisition

$ 400

Litigation contingency accrual

$ 3,700

Litigation contingency paid

$ 2,100

Gain on settlement

$ 1,100

Effects of inventories and open contracts

8,700

PE Op Co. [Member]

Percentage of interests auquired

4.00%

96.00%

Ownership interest purchase in cash

$ 6,000

Reduction in noncontrolling interest

$ 4,400

4,400

Increase (decrease) in additional paid in capital due to acquisition

$ 600

XML

INTERCOMPANY AGREEMENTS. (Details Narrative)
$ / shares in Units, $ in Thousands

1 Months Ended

12 Months Ended

Dec. 15, 2016

$ / shares

Jul. 01, 2015

Number

$ / shares

Dec. 31, 2016

USD ($)

Dec. 31, 2017

USD ($)

Dec. 31, 2016

USD ($)

Dec. 31, 2015

USD ($)

Affiliate Management Agreement [Member]

Agreement term

1 year

Agreement renewal term

1 year

Description of agreement termination

Pacific Ethanol may terminate the AMA, and any subsidiary may terminate the AMA, at any time by providing at least 90 days prior notice of such termination.

Revenues from related party

$ 11,904

$ 12,968

$ 9,857

Ethanol Marketing Agreement [Member] | Kinergy Marketing LLC [Member]

Agreement term

1 year

Agreement renewal term

1 year

Number of plants | Number

9

Description of agreement terms

(i) the estimated purchase price payable by the third-party purchaser of the ethanol, minus (ii) the estimated amount of transportation costs to be incurred, minus (iii) the estimated incentive fee payable to Kinergy, which equals 1% of the aggregate third-party purchase price, provided that the marketing fee shall not be less than $0.015 per gallon and not more than $0.0225 per gallon.

Revenues from related party

8,464

8,029

5,262

Corn Procurement and Handling Agreement [Member] | Pacific Ag. Products, LLC [Member]

Agreement term

1 year

Agreement renewal term

1 year

Description of agreement terms

Each facility appointed PAP as its exclusive agent to solicit, negotiate, enter into and administer, on its behalf, corn supply arrangements to procure the corn necessary to operate its facility.

Services fees (per bushel) | $ / shares

$ 0.03

$ 0.045

Revenues from related party

4,245

4,386

2,910

New Grain Procurement Agreement [Member] | Pacific Aurora [Member] | ACEC [Member]

Agreement term

1 year

Agreement renewal term

1 year

Services fees (per bushel) | $ / shares

$ 0.03

Grain procurement expenses

$ 107

$ 816

Distillers Grains Marketing Agreements [Member] | Pacific Ag. Products, LLC [Member]

Description of agreement terms

Within ten days after a plant delivers co-products to PAP, the plant is paid an amount equal to (i) the estimated purchase price payable by the third-party purchaser of the co-products, minus (ii) the estimated amount of transportation costs to be incurred, minus (iii) the estimated amount of fees and taxes payable to governmental authorities in connection with the tonnage of the co-products produced or marketed, minus (iv) the estimated incentive fee payable to the Company, which equals (a) 5% of the aggregate third-party purchase price for wet corn gluten feed, wet distillers grains, corn condensed distillers solubles and distillers grains with solubles, or (b) 1% of the aggregate third-party purchase price for corn gluten meal, dry corn gluten feed, dry distillers grains, corn germ and corn oil. Each distillers grains marketing agreement had an initial term of one year and successive one year renewal periods at the option of the individual plant.

Revenues from related party

$ 6,020

$ 6,047

$ 4,438

XML

SEGMENTS. (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Net Sales	$ 395,271	$ 445,442	$ 405,202	$ 386,340	$ 441,719	$ 417,806	$ 422,860	$ 342,373	$ 1,632,255	$ 1,624,758	$ 1,191,176
Cost of goods sold									1,626,324	1,570,400	1,180,810
Income (loss) before provision for income taxes									(38,395)	545	(28,907)
Depreciation and amortization									38,651	35,441	23,632
Interest expense									12,938	22,406	12,594
Intersubsegment Eliminations [Member]
Net Sales									(10,362)	(9,198)	(5,262)
Cost of goods sold									(7,685)	(21,176)	(12,477)
Ethanol Production [Member]
Net Sales									1,104,620	1,046,976	710,201
Cost of goods sold									1,098,977	1,015,655	716,877
Income (loss) before provision for income taxes									(27,458)	(6,882)	(32,723)
Depreciation and amortization									37,637	34,528	23,091
Interest expense									5,887	20,794	11,969
Ethanol Production [Member] | Intersegment Net Sales [Member]
Net Sales									1,898	1,169
Ethanol Production [Member] | External Customers [Member]
Net Sales									1,102,722	1,045,807	710,201
Marketing and Distribution [Member]
Net Sales									537,997	586,980	486,237
Cost of goods sold									535,032	575,921	476,410
Income (loss) before provision for income taxes									(2,463)	4,517	3,200
Depreciation and amortization										3	151
Interest expense									1,271	1,404	625
Marketing and Distribution [Member] | Intersegment Net Sales [Member]
Net Sales									8,464	8,029	5,262
Marketing and Distribution [Member] | External Customers [Member]
Net Sales									529,533	578,951	480,975
Corporate Activities [Member]
Income (loss) before provision for income taxes									(8,474)	2,910	616
Depreciation and amortization									1,014	910	390
Interest expense									$ 5,780	$ 208

XML

SEGMENTS. (Details 1) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Assets	$ 720,296	$ 708,238
Ethanol Production [Member]
Assets	583,696	542,688
Marketing and Distribution [Member]
Assets	127,242	146,356
Corporate Assets [Member]
Assets	$ 9,358	$ 19,194

XML

SEGMENTS. (Details Narrative) $ in Thousands	12 Months Ended
	Dec. 31, 2017 USD ($) Number	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)
Number of operating segments | Number	2
Ethanol Production [Member]
Management fees	$ 9,744	$ 9,968	$ 5,957
Marketing and Distribution [Member]
Management fees	$ 2,160	$ 3,000	$ 3,900

XML

PROPERTY AND EQUIPMENT. (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Property, Plant and Equipment, Gross	$ 658,356	$ 577,613
Accumulated Depreciation	(150,004)	(112,423)
Property, Plant and Equipment, Net	508,352	465,190
Facilities And Plant Equipment [Member]
Property, Plant and Equipment, Gross	601,156	530,735
Land [Member]
Property, Plant and Equipment, Gross	8,970	7,771
Other Equipment, Vehicles and Furniture [Member]
Property, Plant and Equipment, Gross	10,189	9,714
Construction in Progress [Member]
Property, Plant and Equipment, Gross	$ 38,041	$ 29,393

XML

PROPERTY AND EQUIPMENT. (Details Narrative) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Depreciation expense	$ 38,651	$ 35,441	$ 23,632
Asset impairment			$ 1,970
Capital Investment Activities [Member]
Capitalized interest	$ 822	$ 1,307

XML

INTANGIBLE ASSET. (Details Narrative) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Intangible assets amount	$ 2,678	$ 2,678
Trade Names [Member] | Kinergy Marketing LLC [Member]
Intangible assets amount		$ 2,678

XML

DERIVATIVES. (Details) - Non Designated Derivative Instruments [Member] - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Cash Collateral Balance [Member]
Derivative assets	$ 3,813	$ 4,331
Commodity Contracts [Member]
Derivative assets	998	978
Derivative liabilities	$ 2,307	$ 4,115

XML

DERIVATIVES. (Details 1) - Non Designated Derivative Instruments [Member] - Commodity Contracts [Member] - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Realized Gains (Losses)	$ (4,165)	$ 1,386	$ (338)
Unrealized Gains (Losses)	2,088	(3,370)	(204)
Cost of goods sold [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized Gains (Losses)	(4,165)	1,386	(338)
Unrealized Gains (Losses)	$ 2,088	$ (3,370)	$ (204)

XML

DERIVATIVES. (Details Narrative) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Recognized gains and losses due to change in fair value	$ (2,077)	$ (1,984)	$ (542)

XML

DEBT (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Long-term borrowings are summarized as follows
Total debt	$ 244,425	$ 201,862
Less: Unamortized debt discount	(1,409)	(1,626)
Less: unamortized debt financing costs	(1,925)	(1,708)
Less short-term portion	(20,000)	(10,500)
Long-term debt	221,091	188,028
Term Loan [Member] | Illinois Corn Processing, LLC [Member]
Long-term borrowings are summarized as follows
Line of credit		32,000
Term debt	22,500
Parent Notes Payable [Member]
Long-term borrowings are summarized as follows
Notes payable	68,948	55,000
Revolving Credit Facility [Member] | Illinois Corn Processing, LLC [Member]
Long-term borrowings are summarized as follows
Line of credit	18,000	0
Kinergy Marketing LLC [Member] | Line of Credit [Member]
Long-term borrowings are summarized as follows
Line of credit	49,477	49,862
Pacific Ethanol Pekin, Inc [Member] | Term Loan [Member]
Long-term borrowings are summarized as follows
Term debt	53,500	64,000
Pacific Ethanol Pekin, Inc [Member] | Revolving Credit Facility [Member]
Long-term borrowings are summarized as follows
Line of credit	32,000
Pacific Aurora [Member] | Line of Credit [Member]
Long-term borrowings are summarized as follows
Line of credit	$ 0	$ 1,000

XML

DEBT (Details 1) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Debt Disclosure [Abstract]
2018	$ 20,000
2019	88,948
2020	20,000
2021	16,000
2022	99,477
Total debt	$ 244,425	$ 201,862

XML

DEBT (Details Narrative) - USD ($)
$ in Thousands

12 Months Ended

Sep. 15, 2017

Sep. 01, 2017

Aug. 07, 2017

Jun. 30, 2017

May 20, 2017

Dec. 15, 2016

Dec. 12, 2016

Dec. 31, 2015

Dec. 15, 2015

Jul. 01, 2015

Dec. 31, 2017

Dec. 31, 2016

Dec. 31, 2015

Feb. 26, 2016

Debt discount

$ 1,409

$ 1,626

Principal balance

244,425

201,862

Term Loan [Member] | Illinois Corn Processing, LLC [Member]

Line of credit

32,000

A-1 Term Loan (Pacific Ethanol West Plants' Term Debt) [Member]

Line of credit

$ 17,003,000

$ 17,003,000

Description of maturity date

mature in June 2016

Debt retiremnt amount

$ 17,003,000

Increased in debt amount

58,766

58,766

$ 41,763

A-1 Term Loan (Pacific Ethanol Central Plants' Term Debt) [Member]

Debt maturity date

Sep. 24, 2017

Description of interest rate

Interest on the term loan facility accrued and could either be paid in cash at a rate of 10.5% per annum or paid in-kind at a rate of 15.0% per annum by adding such interest to the outstanding principal balance.

Line of credit

$ 142,744

Description of debt collateral

Secured through a first-priority lien on substantially all of the Pacific Ethanol Central Plants

Debt discount

$ 2,875

1,152

Paid in kind interest

9,451

Principal balance

$ 155,070,205

Repayment of debt

$ 155,070,205

Credit Agreement [Member] | Illinois Corn Processing, LLC [Member]

Description payment terms

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.

Credit Agreement [Member] | Term Loan [Member] | Illinois Corn Processing, LLC [Member]

Debt face amount

$ 24,000

Description of interest rate

Accrues at a rate equal to 3.75% plus the one-month LIBOR index rate.

Principal payments

$ 1,500

Frequency of periodic payments

Quarterly

Description payment terms

Principal payments in sixteen equal consecutive quarterly installments of $1,500,000 each until September 20, 2021

Note Purchase Agreement [Member] | Notes Payable [Member] | Five Accredited Investors [Member]

Debt face amount

$ 50,000

Description of borrowing terms

Private offering for aggregate gross proceeds of 97% of the principal amount of the Notes sold.

Note Purchase Agreement [Member] | Total Notes Payable [Member] | Five Accredited Investors [Member]

Debt maturity date

Dec. 15, 2019

Description of interest rate

(i) the greater of 1% and the three-month LIBOR, plus 7.0% from the closing 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.

Debt default interest rate

2.00%

Description of debt collateral

Secured by a first-priority security interest in the equity interest held by Pacific Ethanol in its wholly-owned subsidiary, PE Op. Co., which indirectly owns the Company’s plants located on the West Coast.

Second Note Purchase Agreement [Member] | Notes Payable [Member] | Five Accredited Investors [Member]

Debt face amount

$ 13,900

Description of borrowing terms

Private offering for aggregate gross proceeds of 97% of the principal amount of the notes sold.

Revolving Credit Facility [Member] | Illinois Corn Processing, LLC [Member]

Line of credit

18,000

0

Revolving Credit Facility [Member] | Credit Agreement [Member] | Illinois Corn Processing, LLC [Member]

Maximum borrowing capacity

$ 18,000

Unused facility fees

0.75%

Kinergy Marketing LLC [Member] | Line of Credit [Member]

Maximum borrowing capacity

$ 100,000

Line of credit maturity date

Aug. 02, 2022

Description of interest rate

Interest accrues under the line of credit at a rate equal to (i) the three-month London Interbank Offered Rate (“LIBOR”), plus (ii) a specified applicable margin ranging between 1.50% and 2.00%.

Interest rate at end of period

3.44%

Interest margin rate

1.75%

Description of payment made to company

Payments that may be made by Kinergy to the Company as reimbursement for management and other services provided by the Company to Kinergy are limited under the terms of the credit facility to $1,500,000 per fiscal quarter.

Description of collateral

The credit facility is based on Kinergy’s eligible accounts receivable and inventory levels, subject to certain concentration reserves. The credit facility is subject to certain other sublimits, including inventory loan limits.

Unused borrowing capacity

$ 27,399

Line of credit

$ 49,477

49,862

Kinergy Marketing LLC [Member] | Line of Credit [Member] | Maximum [Member]

Unused facility fees

0.38%

Kinergy Marketing LLC [Member] | Line of Credit [Member] | Minimum [Member]

Unused facility fees

0.25%

Pacific Ag. Products, LLC [Member] | Line of Credit [Member]

Description of payment made to company

Payments that may be made by PAP to the Company as reimbursement for management and other services provided by the Company to PAP are limited under the terms of the credit facility to $500,000 per fiscal quarter.

Description of collateral

The credit facility also includes the accounts receivable of PAP as additional collateral

Pacific Ethanol Pekin, Inc [Member] | Credit Agreement [Member] | 1st Farm Credit Services [Member]

Description of interest rate

Annual rate equal to the 30-day LIBOR plus 3.75%, payable monthly

Description of debt covenant

Under the terms of the Pekin Credit Agreement, Pekin is required to maintain not less than $20.0 million in working capital and an annual debt coverage ratio of not less than 1.25 to 1.0.

Pacific Ethanol Pekin, Inc [Member] | Credit Agreement [Member] | 1st Farm Credit Services [Member] | Term Loan [Member]

Debt face amount

$ 64,000

Debt maturity date

Aug. 20, 2021

Pacific Ethanol Pekin, Inc [Member] | Amendment Credit Agreement [Member] | 1st Farm Credit Services [Member]

Description of interest rate

Increase the interest rate under the facilities by 25 basis points to an annual rate equal to the 30-day LIBOR plus 4.00%.

Principal payments

$ 3,500

Description of debt covenant

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.

Description of debt covenant subsequent

Working capital covenant requirement to be at least $13.0 million for the month ended February, 28, 2018.

Pacific Ethanol Pekin, Inc [Member] | Revolving Credit Facility [Member]

Line of credit

$ 32,000

Pacific Ethanol Pekin, Inc [Member] | Revolving Credit Facility [Member] | Credit Agreement [Member] | 1st Farm Credit Services [Member]

Maximum borrowing capacity

$ 32,000

Line of credit maturity date

Feb. 01, 2022

Unused facility fees

0.75%

Description of collateral

Secured by a first-priority security interest in all of Pekin’s assets under the terms of a Security Agreement

Principal payments

$ 3,500

Frequency of periodic payments

Quarterly

Description payment terms

Principal payment of $4.5 million at maturity on August 20, 2021

Pacific Aurora [Member] | Line of Credit [Member]

Line of credit

$ 0

$ 1,000

Pacific Aurora [Member] | Revolving Credit Facility [Member] | Credit Agreement [Member] | CoBank [Member]

Maximum borrowing capacity

$ 30,000

Line of credit maturity date

Feb. 01, 2022

Description of interest rate

Annual rate equal to the 30-day LIBOR plus 4.0%, payable monthly.

Unused facility fees

0.75%

Description of collateral

Secured by a first-priority security interest in all of Pacific Aurora’s assets under the terms of a Security Agreement

Description of debt covenant

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

Maintain not less than $22.5 million in working capital through June 30, 2017, not less than $24.0 million in working capital after June 30, 2017, and an annual debt coverage ratio of not less than 1.50 to 1.00.

Description of borrowing terms

Borrowing availability under the Pacific Aurora Credit Facility automatically declines by $2.5 million on the first day of each June and December beginning on June 1, 2017 through and including December 1, 2020.

XML

PENSION PLANS. (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Components of net periodic benefit costs are as follows:
Loss (gain) recognized in other comprehensive income (expense)	$ (386)	$ 3,660	$ (1,040)
Retirement Plan [Member]
Changes in plan assets:
Fair value of plan assets, beginning	12,423	12,567	13,180
Actual gains (losses)	1,722	523	(298)
Benefits paid	(665)	(667)	(315)
Company contributions	478
Participant contributions
Fair value of plan assets, ending	13,958	12,423	12,567
Amounts recognized in the consolidated balance sheets:
Other liabilities	(5,700)	(6,032)	(3,985)
Accumulated other comprehensive loss (income)	726	1,047	(885)
Components of net periodic benefit costs are as follows:
Service cost	391	223	211
Interest cost	750	686	338
Expected return on plan assets	(674)	(794)	(500)
Net periodic benefit cost	467	115	49
Loss (gain) recognized in other comprehensive income (expense)	$ (321)	$ 1,932	$ (885)
Assumptions used in computation benefit obligations:
Discount rate	3.60%	4.15%	4.23%
Expected long-term return on plan assets	6.00%	6.75%	7.75%

XML

PENSION PLANS. (Details 1) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Components of net periodic benefit costs are as follows:
Loss (gain) recognized in other comprehensive income (expense)	$ (386)	$ 3,660	$ (1,040)
Postretirement Plan [Member]
Changes in plan assets:
Fair value of plan assets, beginning
Benefits paid	(179)	(184)	(35)
Company contributions	157	163	20
Participant contributions	22	22	15
Accumulated/projected benefit obligation	5,565	5,371
Fair value of plan assets, ending
Funded status, (underfunded)/overfunded	(5,565)	(5,371)
Amounts recognized in the consolidated balance sheets:
Accrued liabilties	(240)	(310)
Other liabilities	(5,325)	(5,061)
Accumulated other comprehensive loss (income)	1,508	1,573
Components of net periodic benefit costs are as follows:
Service cost	84	48	32
Interest cost	198	139	65
Expected return on plan assets	134
Net periodic benefit cost	416	187	97
Loss (gain) recognized in other comprehensive income (expense)	$ (65)	$ 1,728	$ (155)
Assumptions used in computation benefit obligations:
Discount rate	3.80%	3.95%	3.67%

XML

PENSION PLANS. (Details 2) $ in Thousands	Dec. 31, 2017 USD ($)
Retirement Plan [Member]
2018	$ 730
2019	740
2020	780
2021	790
2022	830
2023-27	4,820
Total expected benefit payments	8,690
Postretirement Plan [Member]
2018	240
2019	270
2020	300
2021	340
2022	330
2023-27	2,120
Total expected benefit payments	$ 3,600

XML

PENSION PLANS. (Details Narrative)
$ in Thousands

12 Months Ended

Dec. 31, 2017

USD ($)

Retirement Plan [Member]

Expected contributions by the company

$ 1,000

Expected net periodic benefit cost for 2017

740

Postretirement Plan [Member]

Expected net periodic benefit cost for 2017

$ 270

Percentage of pre-Medicare postretirement medical benefits

7.00%

Percentage of adjusting rate assumed health care

For purposes of determining the cost and obligation for pre-Medicare postretirement medical benefits, a 7.0% annual rate of increase in the per capita cost of covered benefits (i.e., health care trend rate) was assumed for the plan in 2018, adjusting to a rate of 4.5% in 2026.

XML

INCOME TAXES. (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Current provision (benefit)	$ (490)	$ 141	$ (8,011)
Deferred provision (benefit)	169	(1,122)	(2,023)
Total	$ (321)	$ (981)	$ (10,034)

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INCOME TAXES. (Details 1)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Effective income tax rate reconciliation
Statutory rate	35.00%	35.00%	35.00%
State income taxes, net of federal benefit	4.00%	6.40%	9.20%
Change in valuation allowance	(34.50%)	(298.80%)	(4.20%)
Impact of Federal tax rate change on deferreds	(28.40%)
Impact of Federal tax rate change on valuation allowance	29.40%
Fair value adjustments and warrant inducements	0.40%	37.20%	2.00%
Noncontrolling interests	(3.20%)
Domestic production gross receipts deduction			(2.90%)
Section 382 reduction to loss carryover			0.10%
Stock compensation	(0.10%)	58.80%	(0.80%)
Non-deductible items	(0.20%)	8.90%	(0.50%)
Other	(1.60%)	(27.50%)	(3.20%)
Effective rate	0.80%	(180.00%)	34.70%

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INCOME TAXES. (Details 2) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Deferred tax assets:
Net operating loss carryforward	$ 40,989	$ 45,709
R&D and AMT credits	1,797	2,465
Railcar contracts	1,415	3,348
Stock-based compensation	738	946
Allowance for doubtful accounts and other assets	637	856
Derivatives	267	1,228
Pension liability	2,939	2,204
Other	2,097	4,316
Total deferred tax assets	50,879	61,072
Deferred tax liabilities:
Property and equipment	(25,194)	(45,757)
Intangibles	(749)	(1,091)
Debt basis
Other	(521)	(1,593)
Total deferred tax liabilities	(26,464)	(48,441)
Valuation allowance	(24,639)	(12,683)	$ (39,838)
Net deferred tax liabilities	$ (224)	$ (52)

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INCOME TAXES. (Details 3) $ in Thousands	Dec. 31, 2017 USD ($)
Federal [Member]
Net operating loss carryforward	$ 154,589
Federal [Member] | 2018-2022 [Member]
Net operating loss carryforward
Federal [Member] | 2023-2027 [Member]
Net operating loss carryforward	13,038
Federal [Member] | 2028-2032 [Member]
Net operating loss carryforward	119,526
Federal [Member] | 2032-2036 [Member]
Net operating loss carryforward	112,248
Federal [Member] | 2017 [Member]
Net operating loss carryforward	59,675
Federal [Member] | 2018 [Member]
Net operating loss carryforward	6,441
Federal [Member] | 2020 [Member]
Net operating loss carryforward	6,308
Federal [Member] | Thereafter [Member]
Net operating loss carryforward	69,483
Federal [Member] | 2019 [Member]
Net operating loss carryforward	6,374
Federal [Member] | 2021 [Member]
Net operating loss carryforward	6,308
State [Member]
Net operating loss carryforward	148,921
State [Member] | 2018-2022 [Member]
Net operating loss carryforward	22,425
State [Member] | 2023-2027 [Member]
Net operating loss carryforward	2,945
State [Member] | 2028-2032 [Member]
Net operating loss carryforward	65,921
State [Member] | 2032-2036 [Member]
Net operating loss carryforward	80,055
State [Member] | 2017 [Member]
Net operating loss carryforward	82,892
State [Member] | 2018 [Member]
Net operating loss carryforward	5,372
State [Member] | 2020 [Member]
Net operating loss carryforward	5,318
State [Member] | Thereafter [Member]
Net operating loss carryforward	44,676
State [Member] | 2019 [Member]
Net operating loss carryforward	5,345
State [Member] | 2021 [Member]
Net operating loss carryforward	$ 5,318

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INCOME TAXES. (Details 4)	12 Months Ended
	Dec. 31, 2016
US Treasury and Government [Member]
Tax Years still open to audit	2014-2016
Arizona [Member]
Tax Years still open to audit	2014-2016
California [Member]
Tax Years still open to audit	2013-2016
Colorado [Member]
Tax Years still open to audit	2013-2016
Idaho [Member]
Tax Years still open to audit	2014-2016
Illinois [Member]
Tax Years still open to audit	2014-2016
Indiana [Member]
Tax Years still open to audit	2014-2016
Iowa [Member]
Tax Years still open to audit	2014-2016
Kansas [Member]
Tax Years still open to audit	2014-2016
Minnesota [Member]
Tax Years still open to audit	2014-2016
Missouri [Member]
Tax Years still open to audit	2014-2016
Nebraska [Member]
Tax Years still open to audit	2014-2016
Oklahoma [Member]
Tax Years still open to audit	2014-2016
Oregon [Member]
Tax Years still open to audit	2014-2016
Texas [Member]
Tax Years still open to audit	2013-2016

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INCOME TAXES. (Details Narrative) - USD ($)
$ in Thousands

12 Months Ended

Dec. 31, 2017

Dec. 31, 2016

Dec. 31, 2015

Valuation allowance

$ 24,639

$ 12,683

$ 39,838

Change in valuation allowance

$ 11,956

(27,155)

Tax benefit related to adjustments to tax asset valuation allowance from prior year

1,500

Revised federal income tax rate

21.00%

Valuation allowance absent of deferred tax liability

$ (10,545)

Decreased gross deferred assets

(10,170)

Accrued tax uncertainties

$ 235

Description of income tax

Other significant provisions of the TCJA that are not yet effective but may impact income taxes in future years include: additional limitations on certain meals and entertainment expenses, the inclusion of commissions and performance-based compensation in determining the excessive compensation limitation, limitation on the current deductibility of net interest expense in excess of 30% of adjusted taxable income, and a limitation of net operating losses generated after fiscal 2018 to 80% of taxable income.

Income tax benefit

$ (321)

(981)

$ (10,034)

PE Central [Member]

Change in valuation allowance

(13,500)

Pacific Aurora [Member]

Change in valuation allowance

$ (11,500)

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PREFERRED STOCK. (Details Narrative) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Preferred undesignated shares authorized	6,734,835
Preferred shares authorized	10,000,000	10,000,000
Preferred stock dividends accrued and paid	$ 1,265	$ 1,269	$ 1,265
Series A Preferred Stock
Preferred shares authorized	1,684,375	1,684,375
Preferred shares outstanding	0	0
Cumulative dividends payable in cash	5.00%
Series B Preferred Stock
Preferred shares authorized	1,580,790	1,580,790
Preferred shares outstanding	926,942	926,942
Preferred stock convertible into common shares, common shares	634,641
Cumulative dividends payable in cash	7.00%
Liquidation preference stock holder	$ 19.50

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COMMON STOCK AND WARRANTS. (Details) - Warrants [Member] - $ / shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Number of Shares
Begining Balance	244,000	382,000	856,000
Warrants exercised	(191,000)	(138,000)	(42,000)
Warrants expired	(49,000)		(432,000)
Ending Balance	4,000	244,000	382,000
Price per Share
Begining Balance
Warrants exercised	6.09	8.43	8.85
Warrants expired			8.85
Ending Balance	735.00
Weighted Average Exercise Price
Begining Balance	106.72	70.87	36.55
Warrants exercised	6.09	8.43	8.85
Warrants expired	444.00		8.85
Ending Balance	735.00	106.72	70.87
Minimum [Member]
Price per Share
Begining Balance	6.09	6.09	6.09
Warrants exercised
Ending Balance	6.09	6.09	6.09
Maximum [Member]
Price per Share
Begining Balance	735.00	735.00	735.00
Warrants exercised
Ending Balance	$ 735.00	$ 735.00	$ 735.00

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COMMON STOCK AND WARRANTS. (Details Narrative) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Stockholders' Equity Note [Abstract]
Warrant inducements	$ 0	$ 0	$ 0
Fair value adjustments for warrants	$ (473)	$ 557	$ (1,641)

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STOCK-BASED COMPENSATION. (Details) - Stock Options [Member] - $ / shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Number of Shares
Begining Balance	240,000	240,000
Expired	(10,000)
Ending Balance	230,000	240,000
Options exercisable at end of year	230,000	240,000
Weighted Average Exercise Price
Begining Balance	$ 4.18	$ 4.18
Expired	3.74
Ending Balance	4.18	4.18
Options exercisable at end of year	$ 4.18	$ 4.18

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STOCK-BASED COMPENSATION. (Details 1)	12 Months Ended
	Dec. 31, 2017 $ / shares shares
$12.90
Number Outstanding | shares	11,000
Weighted Average Remaining Contractual Life (yrs)	3 years 7 months 2 days
Weighted Average Exercise Price | $ / shares	$ 12.90
Number Exercisable | shares	11,000
Weighted Average Exercise Price | $ / shares	$ 12.90
$3.74
Number Outstanding | shares	219,000
Weighted Average Remaining Contractual Life (yrs)	5 years 5 months 19 days
Weighted Average Exercise Price | $ / shares	$ 3.74
Number Exercisable | shares	219,000
Weighted Average Exercise Price | $ / shares	$ 3.74

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STOCK-BASED COMPENSATION. (Details 2) - Restricted Stock - $ / shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Number of Shares
Begining Balance	930,000	463,000	390,000
Issued	664,000	742,000	307,000
Vested	(480,000)	(250,000)	(220,000)
Canceled	(37,000)	(25,000)	(14,000)
Ending Balance	1,077,000	930,000	463,000
Weighted Average Grant Date Fair Value
Begining Balance	$ 6.57	$ 10.00	$ 8.71
Issued	6.65	5.24	10.16
Vested	7.30	9.01	7.94
Canceled	6.08	6.24	10.08
Ending Balance	$ 6.31	$ 6.57	$ 10.00

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STOCK-BASED COMPENSATION. (Details 3) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Total stock-based compensation expense	$ 3,828	$ 2,616	$ 2,019
Employees [Member]
Total stock-based compensation expense	3,303	2,173	1,694
Non-Employees [Member]
Total stock-based compensation expense	$ 525	$ 443	$ 325

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STOCK-BASED COMPENSATION. (Details Narrative) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Total compensation cost related to unvested awards	$ 4,122
Compensation cost weighted average period	1 year 6 months 14 days
2006 Stock Incentive Plan [Member]
Shares authorized	1,715,000
2016 Stock Incentive Plan [Member]
Shares authorized	1,150,000
Stock Options [Member]
Intrinsic values of outstanding options	$ 84	$ 1,319
Fair value of stock vested	$ 3,210	$ 1,142	$ 2,603

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COMMITMENTS AND CONTINGENCIES. (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Capital Leases
2018	$ 613
2019	45
2020	45
2021	34
2022
Thereafter
Total minimum payments	737
Amount representing interest	(22)
Obligations under capital leases	715
Obligations due within one year	(592)	$ (794)
Long-term obligations under capital leases	123	$ 547
Operating Leases
2018	11,841
2019	9,236
2020	7,042
2021	4,074
2022	3,894
Thereafter	5,530
Total minimum payments	$ 41,617

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COMMITMENTS AND CONTINGENCIES. (Details Narrative) - USD ($) $ in Thousands			12 Months Ended
	Dec. 29, 2016	Feb. 27, 2015	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Rent expense			$ 16,572	$ 16,253	$ 10,476
Capital improvement commitments			4,100
Gain on litigation settlement			3,600
Proceeds from legal settlement			3,900
Solar Project [Member]
Capital improvement commitments			10,000
Capital expenditures			7,700
Additional property tax payments			$ 900
property tax rate			5.60%
Western Sugar Contract [Member]
Litigation reserve				2,800
Gain on litigation settlement				$ 1,100
Settlement cliam	$ 1,700
Amount of expectation damages		$ 8,600
Corn contract [Member]
Purchase commitments			$ 21,134
Ethanol contracts [Member]
Sales commitments			$ 90,389
Indexed-price contracts to sell			310,289,000 gallons
Purchase commitments			$ 8,932
Indexed-price purchase contracts			16,149,000 gallons
Co-product contracts [Member]
Sales commitments			$ 35,600

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FAIR VALUE MEASUREMENTS. (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Assets:
Assets	$ 14,956	$ 13,401
Liabilities:
Liabilities		(4,766)
Warrants [Member]
Liabilities:
Liabilities		(651)
Defined Benefit Plan Assets Fixed Income [Member]
Assets:
Assets	$ 5,664	$ 5,481
Liabilities:
Benefit plan allocation percentage	41.00%	44.00%
Defined Benefit Plan Assets International Equity [Member]
Assets:
Assets	$ 2,528	$ 2,006
Liabilities:
Benefit plan allocation percentage	18.00%	16.00%
Defined Benefit Plan Assets Small/Mid U.S. Equity [Member]
Assets:
Assets	$ 2,018	$ 1,802
Liabilities:
Benefit plan allocation percentage	14.00%	15.00%
Derivative Financial Instrument [Member]
Assets:
Assets	$ 998	$ 978
Liabilities:
Liabilities	(2,307)	(4,115)
Defined Benefit Plan Assets Large U.S. Equity [Member]
Assets:
Assets	$ 3,748	$ 3,134
Liabilities:
Benefit plan allocation percentage	27.00%	25.00%
Level 3 [Member]
Assets:
Assets
Liabilities:
Liabilities		(651)
Level 3 [Member] | Warrants [Member]
Liabilities:
Liabilities		(651)
Level 3 [Member] | Defined Benefit Plan Assets Fixed Income [Member]
Assets:
Assets
Level 3 [Member] | Defined Benefit Plan Assets International Equity [Member]
Assets:
Assets
Level 3 [Member] | Defined Benefit Plan Assets Small/Mid U.S. Equity [Member]
Assets:
Assets
Level 3 [Member] | Derivative Financial Instrument [Member]
Assets:
Assets
Liabilities:
Liabilities
Level 3 [Member] | Defined Benefit Plan Assets Large U.S. Equity [Member]
Assets:
Assets
Level 2 [Member]
Assets:
Assets	13,958	12,423
Liabilities:
Liabilities
Level 2 [Member] | Warrants [Member]
Liabilities:
Liabilities
Level 2 [Member] | Defined Benefit Plan Assets Fixed Income [Member]
Assets:
Assets	5,664	5,481
Level 2 [Member] | Defined Benefit Plan Assets International Equity [Member]
Assets:
Assets	2,528	2,006
Level 2 [Member] | Defined Benefit Plan Assets Small/Mid U.S. Equity [Member]
Assets:
Assets	2,018	1,802
Level 2 [Member] | Derivative Financial Instrument [Member]
Assets:
Assets
Liabilities:
Liabilities
Level 2 [Member] | Defined Benefit Plan Assets Large U.S. Equity [Member]
Assets:
Assets	3,748	3,134
Level 1 [Member]
Assets:
Assets	998	978
Liabilities:
Liabilities	(2,307)	(4,115)
Level 1 [Member] | Warrants [Member]
Liabilities:
Liabilities
Level 1 [Member] | Defined Benefit Plan Assets Fixed Income [Member]
Assets:
Assets
Level 1 [Member] | Defined Benefit Plan Assets International Equity [Member]
Assets:
Assets
Level 1 [Member] | Defined Benefit Plan Assets Small/Mid U.S. Equity [Member]
Assets:
Assets
Level 1 [Member] | Derivative Financial Instrument [Member]
Assets:
Assets	998	978
Liabilities:
Liabilities	(2,307)	(4,115)
Level 1 [Member] | Defined Benefit Plan Assets Large U.S. Equity [Member]
Assets:
Assets

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FAIR VALUE MEASUREMENTS. (Details 1) - Original issuance 7/3/2012 $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2016 USD ($) $ / shares shares
Exercise price | $ / shares	$ 6.09
Volatility	40.90%
Risk free interest rate	0.62%
Term (years)	6 months
Market Discount	11.30%
Warrants Outstanding | shares	211,000
Fair value | $	$ 651

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FAIR VALUE MEASUREMENTS. (Details 2) - Level 3 [Member] - Warrants [Member] - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	$ 651	$ 273	$ 1,986
Exercised warrants	(178)	(179)	(72)
Expiration of warrants			(527)
Adjustments to fair value for the period	(473)	557	(1,114)
Ending Balance		$ 651	$ 273

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PARENT COMPANY FINANCIALS. (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Current Assets:
Cash and cash equivalents	$ 49,489	$ 64,259	$ 51,550	$ 62,073
Other current assets	6,841	7,943
Total current assets	203,246	235,201
Property and equipment, net	508,352	465,190
Other Assets:
Other assets	6,020	5,169
Total Assets	720,296	708,238
Current Liabilities:
Total current liabilities	90,706	78,841
Long Term debt, net	244,425	201,862
Warrant liabilities at fair value	2,307	4,115
Other liabilities	6,396	6,101
Total Liabilities	336,596	289,977
Stockholders' Equity:
Common and non-voting common stock	44	40
Additional paid-in capital	927,090	922,698
AAccumulated other comprehensive loss	(2,234)	(2,620)
Accumulated deficit	(568,462)	(532,233)
Total Pacific Ethanol, Inc. stockholders' equity	356,439	387,890
Total Liabilities and Stockholders' Equity	720,296	708,238
Parent Company [Member]
Current Assets:
Cash and cash equivalents	5,314	11,060	$ 20,618	$ 23,915
Receivables from consolidated subsidiaries	3,138	7,203
Other current assets	1,631	6,442
Total current assets	10,083	24,705
Property and equipment, net	1,071	1,433
Other Assets:
Investments in subsidiaries	359,680	363,401
Pacific Ethanol West plant receivable	58,766	58,766
Other assets	1,565	1,110
Total other assets	420,011	423,277
Total Assets	431,165	449,415
Current Liabilities:
Accounts payable and accrued liabilities	2,218	1,758
Payable to subsidiaries	625	1,568
Accrued PE Op Co. purchase	3,828	3,828
Other current liabilities	245	184
Total current liabilities	6,916	7,338
Long Term debt, net	67,530	53,360
Warrant liabilities at fair value		651
Deferred tax liabilities	224	52
Other liabilities	56	124
Total Liabilities	74,726	61,525
Stockholders' Equity:
Preferred stock	1	1
Common and non-voting common stock	44	44
Additional paid-in capital	927,090	922,698
AAccumulated other comprehensive loss	(2,234)	(2,620)
Accumulated deficit	(568,462)	(532,233)
Total Pacific Ethanol, Inc. stockholders' equity	356,439	387,890
Total Liabilities and Stockholders' Equity	$ 431,165	$ 449,415

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PARENT COMPANY FINANCIALS. (Details 1) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Selling, general and administrative expenses									$ 31,516	$ 30,849	$ 26,368
Asset impairment											1,970
Loss from operations	$ (10,598)	$ 3,345	$ (7,109)	$ (11,223)	$ 18,808	$ 393	$ 11,556	$ (7,248)	(25,585)	23,509	(17,972)
Interest expense									(12,938)	(22,406)	(12,594)
Income (loss) before provision for income taxes									(38,395)	545	(28,907)
Provision (benefit) for income taxes									(321)	(981)	(10,034)
Consolidated net income (loss)	$ (13,285)	$ (202)	$ (8,841)	$ (12,636)	$ 13,077	$ (3,518)	$ 5,086	$ (13,226)	(34,964)	1,419	(18,786)
Parent Company [Member]
Management fees from subsidiaries									11,904	12,968	9,857
Selling, general and administrative expenses									18,185	14,491	14,336
Asset impairment											1,970
Loss from operations									(6,281)	(1,523)	(6,449)
Fair value adjustments									473	(557)	1,641
Interest income									4,793	5,964	5,739
Interest expense									(5,829)	(240)	(27)
Other income (expense), net									(95)	1,931
Income (loss) before provision for income taxes									(6,939)	5,575	904
Provision (benefit) for income taxes									(321)	(981)	(10,034)
Income (loss) before equity in earnings of subsidiaries									(6,618)	6,556	10,938
Equity in losses of subsidiaries									(28,346)	(5,137)	(29,724)
Consolidated net income (loss)									$ (34,964)	$ 1,419	$ (18,786)

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PARENT COMPANY FINANCIALS. (Details 2) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operating Activities:
Net income (loss)	$ (13,285)	$ (202)	$ (8,841)	$ (12,636)	$ 13,077	$ (3,518)	$ 5,086	$ (13,226)	$ (34,964)	$ 1,419	$ (18,786)
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Fair value adjustments									(473)	557	(1,641)
Asset impairment											1,970
Deferred income taxes									169	(1,122)	(2,023)
Amortization of debt discounts									636	2,322	716
Changes in operating assets and liabilities:
Accounts receivables									17,562	(25,235)	(15,950)
Other assets									6,738	(3,973)	5,622
Accounts payable and accrued expenses									(5,538)	9,279	(10,045)
Net cash provided by (used in) operating activities									36,509	37,228	(27,993)
Investing Activities:
Additions to property and equipment									(20,866)	(19,171)	(20,507)
Net cash used in investing activities									(50,440)	(14,597)	(6,325)
Financing Activities:
Proceeds from issuances of senior notes									13,530	53,350
Proceeds from warrant stock option exercises									1,202	1,164	368
Net cash provided by (used in) financing activities									(839)	(9,922)	23,795
Net decrease in cash and cash equivalents									(14,770)	12,709	(10,523)
Cash and cash equivalents at beginning of period				64,259				51,550	64,259	51,550	62,073
Cash and cash equivalents at end of period	49,489				64,259				49,489	64,259	51,550
Parent Company [Member]
Operating Activities:
Net income (loss)									(34,964)	1,419	(18,786)
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Equity in losses of subsidiaries									28,346	5,137	29,724
Dividends from subsidiaries									3,500
Depreciation and amortization									830	727	390
Fair value adjustments									(473)	557	(1,641)
Asset impairment											1,970
Deferred income taxes									169	(1,122)	(14,260)
Amortization of debt discounts									636	10
Changes in operating assets and liabilities:
Accounts receivables									4,065	7,302	(5,958)
Other assets									4,356	4,647	(4,139)
Accounts payable and accrued expenses									3,859	(3,741)	604
Accounts payable with subsidiaries									(943)	(9,385)	11,179
Net cash provided by (used in) operating activities									9,381	5,551	(917)
Investing Activities:
Additions to property and equipment									(468)	(465)	(1,483)
Investments in subsidiaries									(28,126)	(50,886)
Purchase of PE OP Co. debt										(17,003)
Net cash used in investing activities									(28,594)	(68,354)	(1,483)
Financing Activities:
Proceeds from issuances of senior notes									13,530	53,350
Proceeds from warrant stock option exercises									1,202	1,164	368
Preferred stock dividend payments									(1,265)	(1,269)	(1,265)
Net cash provided by (used in) financing activities									13,467	53,245	(897)
Net decrease in cash and cash equivalents									(5,746)	(9,558)	(3,297)
Cash and cash equivalents at beginning of period				$ 11,060				$ 20,618	11,060	20,618	23,915
Cash and cash equivalents at end of period	$ 5,314				$ 11,060				$ 5,314	$ 11,060	$ 20,618

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QUARTERLY FINANCIAL DATA (UNAUDITED). (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Net sales	$ 395,271	$ 445,442	$ 405,202	$ 386,340	$ 441,719	$ 417,806	$ 422,860	$ 342,373	$ 1,632,255	$ 1,624,758	$ 1,191,176
Gross profit (loss)	(2,014)	12,065	1,653	(5,773)	27,314	7,021	18,355	1,668	5,931	54,358	10,366
Income (loss) from operations	(10,598)	3,345	(7,109)	(11,223)	18,808	393	11,556	(7,248)	(25,585)	23,509	(17,972)
Net income (loss) attributed to Pacific Ethanol, Inc.	(13,285)	(202)	(8,841)	(12,636)	13,077	(3,518)	5,086	(13,226)	(34,964)	1,419	(18,786)
Preferred stock dividends	(319)	(319)	(315)	(312)	(320)	(319)	(315)	(315)	(1,265)	(1,269)	(1,265)
Income allocated to participating securities					(189)	0	(71)	0		(2)
Net income (loss) available to common stockholders	$ (13,604)	$ (521)	$ (9,156)	$ (12,948)	$ 12,569	$ (3,837)	$ 4,700	$ (13,541)	$ (36,229)	$ 148	$ (20,051)
Basic and diluted income (loss) per common share	$ (0.32)	$ (0.01)	$ (0.22)	$ (0.31)	$ 0.30	$ (0.09)	$ 0.11	$ (0.32)