Edgar Filing: Pacific Ethanol, Inc.

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended June 30, 2014

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

For the transition period from ______ to _______

Commission File Number: 000-21467

PEI_logo_sm

(Exact name of registrant as specified in its charter)

Delaware
(State or other jurisdiction
of incorporation or organization)

41-2170618
(I.R.S. Employer
Identification No.)

400 Capitol Mall, Suite 2060, Sacramento, California

(Address of principal executive offices)

95814

(zip code)

(916) 403-2123

(Registrant’s telephone number, including area code)

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x No o

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

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

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

As of August 13, 2014, there were 23,908,095 shares of Pacific Ethanol, Inc. common stock, $0.001 par value per share, outstanding.

PART I
FINANCIAL INFORMATION

		Page

ITEM 1.	FINANCIAL STATEMENTS.

	Consolidated Balance Sheets as of June 30, 2014 (unaudited) and December 31, 2013	1

	Consolidated Statements of Operations for the Three and Six Months Ended June 30, 2014 and 2013 (unaudited)	3

	Consolidated Statements of Cash Flows for the Six Months Ended June 30, 2014 and 2013 (unaudited)	4

	Notes to Consolidated Financial Statements (unaudited)	6

ITEM 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.	19

ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.	33

ITEM 4.	CONTROLS AND PROCEDURES.	33

PART II

OTHER INFORMATION

ITEM 1.	LEGAL PROCEEDINGS.	34

ITEM 1A.	RISK FACTORS.	35

ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS.	44

ITEM 3.	DEFAULTS UPON SENIOR SECURITIES.	44

ITEM 4.	MINE SAFETY DISCLOSURES.	44

ITEM 5.	OTHER INFORMATION.	44

ITEM 6.	EXHIBITS.	45

SIGNATURES		47

EXHIBITS FILED WITH THIS REPORT

PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS.

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

	June 30,		December 31,
ASSETS	2014		2013
	(unaudited)		*
Current Assets:
Cash and cash equivalents	$	25,923	$	5,151
Accounts receivable, net		43,063		35,296
Inventories		27,580		23,386
Prepaid inventory		14,814		12,315
Other current assets		1,033		3,229
Total current assets		112,413		79,377
Property and equipment, net		155,528		155,194
Other Assets:
Intangible assets, net		3,023		3,260
Other assets		1,749		3,218
Total other assets		4,772		6,478
Total Assets	$	272,713	$	241,049

_______________

* Amounts derived from the audited financial statements for the year ended December 31, 2013.

See accompanying notes to consolidated financial statements.

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

	June 30,			December 31,
LIABILITIES AND STOCKHOLDERS’ EQUITY	2014			2013
	(unaudited)			*
Current Liabilities:
Accounts payable – trade	$	16,619		$	11,071
Accrued liabilities		10,440			5,851
Current portion – capital leases		4,802			4,830
Current portion – long-term debt due to a related party		–			750
Other current liabilities		1,419			5,714
Total current liabilities		33,280			28,216

Long-term debt, net of current portion		38,374			98,408
Accrued preferred dividends		2,194			3,657
Capital leases, net of current portion		3,710			6,041
Warrant liabilities at fair value		22,763			8,215
Other liabilities		4,495			1,611

Total Liabilities		104,816			146,148

Commitments and Contingencies (Notes 4, 5 and 7)

Stockholders’ Equity:
Pacific Ethanol, Inc. Stockholders’ Equity:
Preferred stock, $0.001 par value; 10,000,000 shares authorized; Series A: 1,684,375 shares authorized; 0 shares issued and outstanding as of June 30, 2014 and December 31, 2013; Series B: 1,580,790 shares authorized; 926,942 shares issued and outstanding as of June 30, 2014 and December 31, 2013; liquidation preference of $20,270 as of June 30, 2014		1			1
Common stock, $0.001 par value; 300,000,000 shares authorized; 21,234,805 and 16,126,287 shares issued and outstanding as of June 30, 2014 and December 31, 2013, respectively		21			16
Additional paid-in capital		687,026			621,557
Accumulated deficit		(528,237	)		(532,356	)
Total Pacific Ethanol, Inc. Stockholders’ Equity		158,811			89,218
Noncontrolling interests		9,086			5,683
Total Stockholders’ Equity		167,897			94,901
Total Liabilities and Stockholders’ Equity	$	272,713		$	241,049

_______________
* Amounts derived from the audited financial statements for the year ended December 31, 2013.

See accompanying notes to consolidated financial statements.

PACIFIC ETHANOL, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS

(unaudited, in thousands, except per share data)

	Three Months Ended June 30,						Six Months Ended June 30,
	2014			2013			2014			2013

Net sales	$	321,144		$	233,808		$	575,687		$	459,267
Cost of goods sold		287,568			226,843			503,566			451,456
Gross profit		33,576			6,965			72,121			7,811
Selling, general and administrative expenses		4,315			3,133			7,985			7,138
Income from operations		29,261			3,832			64,136			673
Fair value adjustments and warrant inducements		485			1,437			(35,359	)		745
Interest expense, net		(2,886	)		(3,972	)		(7,237	)		(7,453	)
Gain (loss) on extinguishments of debt		(2,363	)		(39	)		(2,363	)		778
Other expense, net		(335	)		(128	)		(562	)		(215	)
Income (loss) before provision for income taxes		24,162			1,130			18,615			(5,472	)
Provision for income taxes		7,196			–			10,466			–
Consolidated net income (loss)		16,966			1,130			8,149			(5,472	)
Net (income) loss attributed to noncontrolling interests		(1,394	)		(79	)		(3,403	)		1,069
Net income (loss) attributed to Pacific Ethanol	$	15,572		$	1,051		$	4,746		$	(4,403	)
Preferred stock dividends	$	(315	)	$	(315	)	$	(627	)	$	(627	)
Income (loss) available to common stockholders	$	15,257		$	736		$	4,119		$	(5,030	)
Net income (loss) per share, basic	$	0.77		$	0.07		$	0.23		$	(0.48	)
Net income (loss) per share, diluted	$	0.68		$	0.07		$	0.20		$	(0.48	)
Weighted-average shares outstanding, basic		19,903			10,853			18,053			10,462
Weighted-average shares outstanding, diluted		22,276			12,135			20,514			10,462

See accompanying notes to consolidated financial statements.

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

	Six Months Ended June 30,
	2014			2013
Operating Activities:
Consolidated net income (loss)	$	8,149		$	(5,472	)
Adjustments to reconcile consolidated net income (loss) to net cash provided by (used in) operating activities:
Depreciation and amortization of intangibles		6,438			5,959
Deferred income taxes		2,874			–
Interest expense added to Plant Owners’ debt		–			4,562
Loss (gain) on extinguishments of debt		2,363			(778	)
Fair value adjustments on convertible debt and warrants		34,559			(1,531	)
Amortization of debt discount		1,764			711
Amortization of deferred financing fees		1,077			516
Non-cash compensation		743			965
Derivative instruments		(517	)		484
Bad debt expense		(34	)		192
Changes in operating assets and liabilities:
Accounts receivable		(7,733	)		(10,333	)
Inventories		(4,194	)		(2,913	)
Prepaid expenses and other assets		3,058			(220	)
Prepaid inventory		(2,499	)		(916	)
Accounts payable and accrued expenses		5,282			5,029
Net cash provided by (used in) operating activities		51,330			(3,745	)
Investing Activities:
Additions to property and equipment		(6,535	)		(918	)
Purchases of New PE Holdco ownership interests		–			(1,836	)
Net cash used in investing activities		(6,535	)		(2,754	)
Financing Activities:
Proceeds from equity offering		26,073			–
Proceeds from exercise of warrants		18,240			2,064
Proceeds from senior notes		–			22,192
Proceeds from series A and B convertible notes		–			14,000
Proceeds from Plant Owners’ borrowings		–			4,000
Principal payments on senior notes		(13,984	)		(4,379	)
Principal payment on related party note		(750	)		–
Parent purchases of Plant Owners’ debt		(17,038	)		(25,273	)
Net proceeds from Kinergy’s line of credit		2,329			3,124
Principal payments on Plant Owners’ borrowings		(35,378	)		(7,622	)
Payments on capital leases		(2,450	)		(23	)
Debt issuance costs		(438	)		(1,560	)
Preferred stock dividends paid		(627	)		(627	)
Net cash provided by (used in) financing activities		(24,023	)		5,896
Net increase (decrease) in cash and cash equivalents		20,772			(603	)
Cash and cash equivalents at beginning of period		5,151			7,586
Cash and cash equivalents at end of period	$	25,923		$	6,983

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

Supplemental Information:
Interest paid	$	4,520	$	1,472
Income taxes paid	$	3,215	$	–
Noncash financing and investing activities:
Reclass of warrant liability to equity upon warrant exercises	$	20,008	$	260
Preferred stock dividends paid in common stock	$	1,463	$	732
Reclass of noncontrolling interests to APIC upon acquisitions of ownership positions in New PE Holdco	$	–	$	9,087
Original discount on senior and convertible debt	$	–	$	8,558
Corn oil separation capital lease	$	–	$	5,287
Debt extinguished with issuance of common stock	$	–	$	3,968

See accompanying notes to consolidated financial statements.

PACIFIC ETHANOL, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)

ORGANIZATION AND BASIS OF PRESENTATION.

Organization and Business – The consolidated financial statements include, for all periods presented, the accounts of Pacific Ethanol, Inc., a Delaware corporation (“Pacific Ethanol”), and its direct and indirect subsidiaries, 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.,” formerly, New PE Holdco LLC, a Delaware limited liability company), which owns the Plant Owners (as defined below) (collectively, the “Company”).

The Company is the leading producer and marketer of low-carbon renewable fuels in the Western United States. The Company also sells ethanol co-products, including wet distillers grain (“WDG”), a nutritious animal feed, and corn oil. Serving integrated oil companies and gasoline marketers who blend ethanol into gasoline, the Company provides transportation, storage and delivery of ethanol through third-party service providers in the Western United States, primarily in California, Arizona, Nevada, Utah, Oregon, Colorado, Idaho and Washington. The Company had a 91% and an 85% ownership interest in PE Op Co., the owner of four ethanol production facilities, as of June 30, 2014 and 2013, respectively. The facilities are near their respective fuel and feed customers, offering significant timing, transportation cost and logistical advantages. The Company sells ethanol produced by the Pacific Ethanol Plants (as defined below) and unrelated third parties to gasoline refining and distribution companies, sells its WDG to dairy operators and animal feed distributors and sells its corn oil to poultry and biodiesel customers.

The Company manages the production and operation of the following four ethanol production facilities: Pacific Ethanol Madera LLC, Pacific Ethanol Columbia, LLC, Pacific Ethanol Stockton LLC and Pacific Ethanol Magic Valley, LLC (collectively, the “Pacific Ethanol Plants”) and their holding company, Pacific Ethanol Holding Co. LLC (“PEHC,” and together with the Pacific Ethanol Plants, the “Plant Owners”). PEHC is a wholly-owned subsidiary of PE Op Co. These four facilities have an aggregate annual ethanol production capacity of up to 200 million gallons. As of June 30, 2014, all four facilities were operating. On April 30, 2014, the Company’s previously idled facility in Madera, California commenced producing ethanol. 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.

Reverse Stock Split – On May 14, 2013, the Company effected a one-for-fifteen reverse stock split. All share and per share information has been restated to retroactively show the effect of this stock split.

Liquidity – During the three and six months ended June 30, 2014, the Company funded its operations primarily from cash on hand, cash provided by operations, proceeds from an equity offering and warrant exercises and borrowings under its credit facilities.

The Company’s current available capital resources consist of cash on hand and amounts available for borrowing under Kinergy’s credit facility. In addition, the Plant Owners have credit facilities for use in the operations of the Pacific Ethanol Plants. The Company expects that its future available capital resources will consist primarily of its remaining cash balances, cash flow from operations, if any, amounts available for borrowing, if any, under Kinergy’s credit facility, cash generated from Kinergy’s ethanol marketing business, fees paid under the asset management agreement relating to the Company’s operation of the Pacific Ethanol Plants, cash proceeds from warrant exercises and distributions, if any, in respect of the Company’s ownership interest in PE Op Co.

The Company believes that current and future available capital resources, revenues generated from operations, and other existing sources of liquidity, including its credit facilities, will be adequate to meet its anticipated working capital and capital expenditure requirements for at least the next twelve months.

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 WDG to dairy operators and animal feed distributors and sells corn oil to poultry and biodiesel customers generally without requiring collateral.

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

Of the accounts receivable balance, approximately $28,931,000 and $27,487,000 at June 30, 2014 and December 31, 2013, respectively, were used as collateral under Kinergy’s operating line of credit. The allowance for doubtful accounts was not material as of June 30, 2014 or December 31, 2013. The Company does not have any off-balance sheet credit exposure related to its customers.

Provision for Income Taxes – For the three and six months ended June 30, 2014, the Company generated income subject to income tax, and as a result, applied a portion of its net operating loss carryforwards to its taxable income and recorded a gross provision for income taxes of $18.5 million. Further, the Company reversed $8.0 million of its valuation allowance against its net tax assets, resulting in a net provision for income taxes of $10.5 million for the six months ended June 30, 2014.

Conversion of New PE Holdco LLC – On April 1, 2014, New PE Holdco LLC was converted from a Delaware limited liability company to a Delaware C-corporation and changed its name to PE Op Co.

Basis of Presentation–Interim Financial Statements – The accompanying unaudited consolidated financial statements and related notes have been prepared in accordance with accounting principles generally accepted in the United States for interim financial information and the instructions to Form 10-Q and Rule 10-01 of Regulation S-X. Results for interim periods should not be considered indicative of results for a full year. These interim consolidated financial statements should be read in conjunction with the consolidated financial statements and related notes contained in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013. The accounting policies used in preparing these consolidated financial statements are the same as those described in Note 1 to the consolidated financial statements in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013. In the opinion of management, all adjustments (consisting of normal recurring adjustments) considered necessary for a fair statement of the results for interim periods have been included. All significant intercompany accounts and transactions have been eliminated in consolidation.

The preparation of the consolidated financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates are required as part of determining the fair value of warrants and conversion features, allowance for doubtful accounts, estimated lives of property and equipment and intangibles, 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. Actual results and outcomes may materially differ from management’s estimates and assumptions.

Recently Issued Accounting Pronouncements – In May 2014, the Financial Accounting Standards Board issued new guidance on the recognition of revenue. The guidance 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 will be effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period. The Company’s adoption begins with the first fiscal quarter of fiscal year 2017. Early adoption is not permitted. The Company is currently evaluating the impact of the adoption of this accounting standard update on its consolidated results of operations and financial position.

PACIFIC ETHANOL PLANTS.

Consolidation of PE Op Co. – The Company concluded that since PE Op Co.’s inception, through the point the Company became a 91% owner, PE Op Co. was a variable interest entity because the other owners of PE Op Co., due to the Company’s involvement through its contractual arrangements, at all times lacked the power to direct the activities that most significantly impacted its economic performance. However, since the Company’s recent acquisition bringing its ownership interest in PE Op Co. to 91%, the Company has obtained sufficient control both by way of agreements as well as based on structural control of PE Op Co., such that PE Op Co. is no longer considered a variable interest entity, and as such the Company consolidates PE Op Co. under the voting rights model. Noncontrolling interests increased from $5,683,000 at December 31, 2013 to $9,086,000 at June 30, 2014 due to net income attributed to noncontrolling interests of $3,403,000 for the six months ended June 30, 2014.

The Company’s acquisition of its ownership interest in PE Op Co. does not impact the Company’s rights or obligations under any of its contractual arrangements. Further, creditors of PE Op Co. or its subsidiaries do not have recourse to the Company. Since its acquisition, the Company has not provided any additional support to PE Op Co. beyond the terms of its contractual arrangements.

INVENTORIES.

Inventories consisted primarily of bulk ethanol and unleaded fuel, and are valued at the lower-of-cost-or-market, with cost determined on a first-in, first-out basis. Inventory balances consisted of the following (in thousands):

	June 30, 2014		December 31, 2013
Finished goods	$	17,616	$	10,287
Raw materials		5,313		9,418
Work in progress		3,721		2,766
Other		930		915
Total	$	27,580	$	23,386

DERIVATIVES.

The business and activities of the Company expose it to a variety of market risks, including risks related to changes in commodity prices and interest rates. 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 three and six months ended June 30, 2014 and 2013, 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 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 gains of $448,000 and losses of $479,000 as the change in the fair value of these contracts for the three months ended June 30, 2014 and 2013, respectively. The Company recognized gains of $517,000 and losses of $484,000 as the change in the fair value of these contracts for the six months ended June 30, 2014 and 2013, respectively.

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

		Realized Gains (Losses)
		Three Months Ended June 30,
Type of Instrument	Statements of Operations Location	2014		2013
Commodity contracts	Cost of goods sold	$	465	$	(29	)
		$	465	$	(29	)

		Unrealized Losses
		Three Months Ended June 30,
Type of Instrument	Statements of Operations Location	2014			2013
Commodity contracts	Cost of goods sold	$	(17	)	$	(450	)
		$	(17	)	$	(450	)

		Realized Gains (Losses)
		Six Months Ended June 30,
Type of Instrument	Statements of Operations Location	2014		2013
Commodity contracts	Cost of goods sold	$	549	$	(102	)
		$	549	$	(102	)

		Unrealized Losses
		Six Months Ended June 30,
Type of Instrument	Statements of Operations Location	2014			2013
Commodity contracts	Cost of goods sold	$	(32	)	$	(382	)
		$	(32	)	$	(382	)

DEBT.

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

	June 30, 2014			December 31, 2013
Kinergy operating line of credit	$	21,371		$	19,042
Senior unsecured notes		–			13,984
Plant Owners’ third-party term debt		58,766			58,766
Plant Owners’ lines of credit		–			35,378
Note payable to related party		–			750
		80,137			127,920
Less: Parent purchased Plant Owners’ term debt		(41,763	)		(27,088	)
Total Consolidated Debt		38,374			100,832
Less: Unamortized discount on senior unsecured notes convertible notes		–			(1,674	)
		38,374			99,158
Less short-term portion		–			(750	)
Long-term debt	$	38,374		$	98,408

Kinergy Operating Line of Credit – For the three and six months ended June 30, 2014, Kinergy borrowed net $4,065,000 and $2,329,000 on its working capital line of credit, respectively. As of June 30, 2014, Kinergy had an available borrowing base under the credit facility of $8,629,000.

Senior Unsecured Notes – For the three and six months ended June 30, 2014, the Company paid in cash $977,000 and $13,984,000 on its senior unsecured notes, respectively. These notes were fully retired at June 30, 2014.

Plant Owners’ Term Debt and Operating Lines of Credit – The Plant Owners’ debt as of June 30, 2014 consisted of a $32,487,000 tranche A-1 term loan and a $26,279,000 tranche A-2 term loan. Pacific Ethanol, Inc., holds a combined $41,763,000 of these term loans, which are eliminated in consolidation. The term debt requires monthly interest payments at a floating rate equal to the three-month LIBOR or the Prime Rate of interest, at the Plant Owners’ election, plus 10.0%. The revolving credit facilities require monthly interest payments at a floating rate equal to the three-month LIBOR or the Prime Rate of interest, at the Plant Owners’ election, plus 10.0% and 5.5% for the $19,500,000 and $15,000,000 facilities, respectively. At June 30, 2014, the average interest rate was approximately 11.0%. Repayments of principal are based on available free cash flow of the Plant Owners, until maturity, when all principal amounts are due.

For the three and six months ended June 30, 2014, the Company paid in cash $16,000,000 and $35,378,000 on its revolving credit facilities. As of June 30, 2014, the Company had no outstanding principal balances on these revolving credit facilities and an aggregate borrowing availability of $34,500,000.

Debt Modifications – On April 1, 2014, the Company entered into amendments to its credit facilities and term loan arrangements to achieve the following changes:

Adjust the terms of the credit agreements to take into account a restart of the Company’s Madera, California facility;

Reduce the Company’s revolving credit facility from $35,000,000 to $20,000,000 while increasing the maximum amount of the term loan outstanding to $65,766,000, allowing the Company to immediately borrow an additional $7,000,000. The additional $7,000,000 in borrowings was subject to an original issue discount of 6.25%, representing loan fees payable to the lenders, resulting in net proceeds from the additional borrowings of approximately $6,600,000. The Company used the net proceeds of the additional loan to restart operations at the Company’s Madera, California facility. The Company has since repaid the additional loan in full;

Increase to $24,000,000 from $14,000,000 the level of permitted indebtedness, including capital lease liabilities that may be incurred for yield enhancing equipment or processing and separation equipment for corn oil and corn syrup at the Company’s ethanol production facilities; and

Maintain the Company’s new revolving credit facility at $15,000,000 but allow the Company to terminate in whole or permanently reduce in part in $1,000,000 increments the lenders’ aggregate commitment.

Parent Purchase of Debt – On June 6, 2014, the Company purchased $14,675,000 of term debt for $17,038,000 in cash, reducing its consolidated plant term debt by $14,675,000, and recorded a $2,363,000 loss on extinguishment of debt for the amount paid in excess of the principal balance .

Note Payable to Related Party – The Company repaid in cash its note payable to its Chief Executive Officer totaling $750,000 on March 31, 2014.

COMMON STOCK AND WARRANTS.

Warrant Exercises – During the three and six months ended June 30, 2014, certain holders exercised warrants and received an aggregate of 1,250,300 and 3,138,000 shares of the Company’s common stock upon payment of an aggregate of $6,110,000 and $18,240,000 in cash, respectively. During the three and six months ended June 30, 2013, certain holders exercised warrants and received an aggregate of 267,700 shares of the Company’s common stock upon payment of an aggregate of $2,064,000 in cash.

During the three and six months ended June 30, 2014, the Company paid an aggregate of $800,000 in cash to certain warrant holders as an inducement to exercise their warrants and recorded an expense of $800,000. During the three and six months ended June 30, 2014, certain warrant holders exercised warrants on a cashless basis and received 291,000 shares of the Company’s common stock.

Equity Offering – In April 2014, the Company issued 1,750,000 shares of its common stock in a public offering for net proceeds of $26,073,000.

Grants of Stock – In June 2014, the Company granted an aggregate of 24,267 shares of restricted stock to non-employee members of the Company’s Board of Directors that vest on the earlier of (i) the date of the Company’s 2015 annual meeting of stockholders, or (ii) July 31, 2015, which had a grant date fair value of $15.21 per share. In June 2014, the Company granted an aggregate of 129,514 shares of restricted stock to the Company’s executive officers and other eligible employees that vest in equal amounts on each of April 1, 2015, 2016 and 2017, which had a grant date fair value of $15.21 per share.

COMMITMENTS AND CONTINGENCIES.

Sales Commitments – At June 30, 2014, the Company had entered into sales contracts with its major customers to sell certain quantities of ethanol, WDG, syrup and corn oil. The Company had open ethanol indexed-price contracts for 140,374,000 gallons of ethanol as of June 30, 2014. The Company had open WDG, syrup and corn oil fixed-price sales contracts valued at $667,000 and open indexed-price sales contracts for 1.8 million pounds of corn oil and 2,000 tons of WDG and syrup as of June 30, 2014. These sales contracts are scheduled to be completed throughout 2014.

Purchase Commitments – At June 30, 2014, the Company had fixed-price purchase contracts with its suppliers to purchase $6,530,000 of ethanol and indexed-price contracts to purchase 20,776,000 gallons of ethanol. These contracts are scheduled to be satisfied throughout the remainder of 2014.

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

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 alleges 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 seeks 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 attorney’s fees. The Company has since answered the complaint and 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 are similar to those filed against Pacific Ethanol, Inc. in May 2013. These two cases, currently pending in the United States District Court for the Eastern District of California and United States District Court for the Eastern District of Idaho, respectively, have been 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. is pending, in accordance with a Conditional Transfer Order issued by the Judicial Panel on Multidistrict Litigation on March 27, 2014. Although PE Stockton and PE Magic Valley do separate and market corn oil, the Company, 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. The Company, PE Stockton and PE Magic Valley are vigorously presenting defenses that include noninfringement, unenforceability, and invalidity of each of the patents at issue. Discovery in all three cases closes September 23, 2014.

8. 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.

The Company recorded its warrants issued from 2010 through 2013 at fair value and designated them as Level 3 on their issuance dates.

Warrants – Except for the warrants issued on September 26, 2012, the Company’s warrants have been valued using a Monte Carlo Binomial Lattice-Based valuation methodology, adjusted for marketability restrictions. The warrants issued on September 26, 2012, did not contain any anti-dilution protection features, and as a result, the warrants were valued using the Black-Scholes Valuation Model. Of the various inputs used, the volatility and the current price of the Company’s common stock most significantly impact the fair value adjustments of the warrants. As the price of the Company’s common stock increases or decreases, the valuation of the warrants will increase or decrease, respectively. As the estimated volatility of the Company’s common stock increases or decreases quarter-over-quarter, the valuation of the warrants will increase or decrease, respectively. These changes may result in significantly higher or lower fair value measurements from period to period.

Significant assumptions used and related fair values for the Company’s warrants as of June 30, 2014 were as follows:

Original Issuance	Exercise Price	Volatility	Risk-Free Interest Rate	Term (years)	Discount for marketability restrictions		Warrants Outstanding		Fair Value
06/21/2013	$7.59	52.6%	0.11%	0.99		20.6%		1,051,200	$	6,636,500
03/28/2013	$7.59	55.1%	0.09%	0.70		18.7%		295,700		1,891,800
09/26/2012	$8.85	52.0%	0.11%	1.24		38.7%		1,637,500		7,078,200
07/3/2012	$6.09	56.3%	0.88%	3.01		35.7%		831,200		5,515,000
12/13/2011	$8.43	54.3%	0.68%	2.46		31.8%		281,500		1,641,900
								4,097,100	$	22,763,400

Significant assumptions used and related fair values for the Company’s warrants as of December 31, 2013 were as follows:

Original Issuance	Exercise Price	Volatility	Risk-Free Interest Rate	Term (years)	Discount for marketability restrictions		Warrants Outstanding		Fair Value
03/28/2013	$7.59	52.4%	0.13%	1.20		22.7%		788,000	$	495,000
06/21/2013	$7.59	52.4%	0.13%	1.24		22.7%		1,051,000		660,000
01/11/2013	$6.32	63.3%	1.27%	4.03		43.8%		1,709,000		2,892,000
09/26/2012	$8.85	58.5%	0.38%	1.74		42.3%		1,771,000		702,000
07/3/2012	$6.09	61.2%	1.27%	3.51		40.2%		1,812,000		3,008,000
07/3/2012	$5.47	52.8%	0.01%	0.01		42.3%		804,000		3,000
12/13/2011	$8.43	60.4%	0.78%	2.95		37.9%		306,000		455,000
								8,241,000	$	8,215,000

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

The following table summarizes fair value measurements by level at June 30, 2014 (in thousands):

	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts⁽¹⁾	$	405	$	–	$	–	$	405
Total Assets	$	405	$	–	$	–	$	405

Liabilities:
Warrants⁽²⁾	$	–	$	–	$	22,763	$	22,763
Commodity contracts⁽³⁾		336		–		–		336
Total Liabilities	$	336	$	–	$	22,763	$	23,099

__________

(1) Included in other current assets in the consolidated balance sheets.

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

(3) Included in other current liabilities in the consolidated balance sheets.

The following table summarizes fair value measurements by level at December 31, 2013 (in thousands):

	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts⁽¹⁾	$	961	$	–	$	–	$	961
Total Assets	$	961	$	–	$	–	$	961

Liabilities:
Warrants⁽²⁾	$	–	$	–	$	8,215	$	8,215
Commodity contracts⁽³⁾		859		–		–		859
Total Liabilities	$	859	$	–	$	8,215	$	9,074

__________

(1) Included in other current assets in the consolidated balance sheets.

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

(3) Included in accrued liabilities in the consolidated balance sheets.

For fair value measurements using significant unobservable inputs (Level 3), 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. The changes in the Company’s fair value of its Level 3 inputs with respect to its warrants were as follows (in thousands):

Fair value of warrants, December 31, 2013	$	8,215
Adjustments to fair value for the period		34,559
Exercises of warrants		(20,008	)
Expiration of warrants		(3	)
Fair value of warrants, June 30, 2014	$	22,763

9.	EARNINGS PER SHARE.

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

	Three Months Ended June 30, 2014
	Income Numerator			Shares Denominator		Per-Share Amount
Net income attributed to Pacific Ethanol	$	15,572
Less: Preferred stock dividends		(315	)
Basic income per share:
Income available to common stockholders	$	15,257			19,903	$	0.77

Add: Warrants		–			2,373
Diluted income per share:
Income available to common stockholders	$	15,257			22,276	$	0.68

	Three Months Ended June 30, 2013
	Income Numerator			Shares Denominator		Per-Share Amount
Net income attributed to Pacific Ethanol	$	1,051
Less: Preferred stock dividends		(315	)
Basic income per share:
Income available to common stockholders	$	736			10,853	$	0.07

Add: Convertible debt		61			1,282
Diluted income per share:
Income available to common stockholders	$	797			12,135	$	0.07

	Six Months Ended June 30, 2014
	Income Numerator			Shares Denominator		Per-Share Amount
Net income attributed to Pacific Ethanol	$	4,746
Less: Preferred stock dividends		(627	)
Basic income per share:
Income available to common stockholders	$	4,119			18,053	$	0.23

Add: Warrants		–			2,461
Diluted income per share:
Income available to common stockholders	$	4,119			20,514	$	0.20

	Six Months Ended June 30, 2013
	Loss Numerator			Shares Denominator		Per-Share Amount
Net loss attributed to Pacific Ethanol	$	(4,403	)
Less: Preferred stock dividends		(627	)
Basic and diluted loss per share:
Loss available to common stockholders	$	(5,030	)		10,462	$	(0.48	)

There were an aggregate of 621,000 and 617,000 potentially dilutive weighted-average shares from the Company’s outstanding convertible Series B Preferred Stock for the three and six months ended June 30, 2014, respectively. These convertible securities were not considered in calculating diluted net income (loss) per share for the three and six months ended June 30, 2013, as their effect would have been anti-dilutive.

10.

RELATED PARTY TRANSACTIONS.

Preferred Dividends – The Company recorded preferred stock dividends of $315,000 for each of the three months ended June 30, 2014 and 2013. The Company recorded preferred stock dividends of $627,000 for each of the six months ended June 30, 2014 and 2013. For the years ended December 31, 2009, 2010 and 2011, the Company accrued but did not pay any preferred stock dividends. For the years ended December 31, 2012 and 2013, the Company paid its accrued dividends in cash.

Beginning in 2012, the Company entered into a series of agreements with the parties to whom unpaid dividends were owed under which the Company issued shares of its common stock in satisfaction of a portion of the accrued and unpaid dividends. In connection with each payment of accrued and unpaid dividends, the payees agreed to forebear for a period of time from exercising any rights they may have with the respect to accrued and unpaid dividends. The following table summarizes the details of the Company’s agreements with the holders of its Series B Preferred Stock:

Agreement Date	Amount of Dividends Paid		Shares of Common Stock Issued		Extended Forbearance Date

August 12, 2012	$	732,000		157,000	January 1, 2014
December 26, 2012		732,000		144,500	June 30, 2014
March 27, 2013		732,000		139,000	September 30, 2014
July 26, 2013		731,000		175,000	December 31, 2014
September 17, 2013		731,000		197,000	March 31, 2015
May 23, 2014		1,463,000		120,000	November 30, 2015
Total	$	5,121,000		932,500

Accrued and unpaid dividends	$	2,194,000

The Company believes it has adequate liquidity to continue to pay quarterly dividends in cash for at least the next twelve months. The Company may continue to pay down the balance of accrued and unpaid dividends in respect of its Series B Preferred Stock by issuing additional shares of common stock. The Company does not believe that these contemplated dividend payments in cash and stock will materially impact its liquidity. If the Company fails to make ongoing quarterly cash dividend payments, it will be in default under the terms of its agreements with the holders of its Series B Preferred Stock and the holders’ current forbearance through November 30, 2015 will be ineffective.

Note Payable to Related Party – The Company had a note payable to its Chief Executive Officer totaling $750,000 which was due on March 31, 2014. On March 31, 2014, the Company paid in cash the outstanding balance of the note payable.

11. SUBSEQUENT EVENTS.

Warrant Exercises – From July 1, 2014 through August 13, 2014, certain holders exercised warrants in cash for an aggregate of 2,673,290 shares of the Company’s common stock for aggregate cash payments to the Company of $20,868,034. Also during that period, the Company paid an aggregate of $1,471,000 in cash to certain warrant holders as an inducement to exercise their warrants.

A summary as of August 13, 2014 of outstanding warrants, which the Company recorded at fair value, with a weighted-average exercise price of $7.81, is as follows:

Issuance Date	Expiration Date	Exercise Price	Warrants Outstanding
06/21/2013	06/21/2015	$7.59		82,500
03/28/2013	03/28/2015	$7.59		61,900
09/26/2012	09/26/2015	$8.85		748,300
07/3/2012	07/03/2017	$6.09		390,500
12/13/2011	12/13/2016	$8.43		140,500
				1,423,700

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

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

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

fluctuations in the costs of key production input commodities, including corn and natural gas;

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

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

our ability to successfully manage and operate our ethanol production facilities;

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

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

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

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

Overview

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

We market all the ethanol produced by four ethanol production facilities located in California, Idaho and Oregon, or the Pacific 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 market ethanol through our subsidiary Kinergy Marketing LLC, or Kinergy. We also market ethanol co-products, including wet distillers grains, or WDG, and corn oil, for the Pacific Ethanol Plants.

We have extensive customer relationships throughout the Western United States. Our ethanol customers are integrated oil companies and gasoline marketers who blend ethanol into gasoline. 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, primarily in California, Arizona, Nevada, Utah, Oregon, Colorado, Idaho and Washington. Our WDG customers are dairies and feedlots located near the Pacific Ethanol Plants. Our corn oil is sold to poultry and biodiesel customers.

We have extensive supplier relationships throughout the Western and Midwestern United States. In some cases, we have marketing agreements with suppliers to market all of the output of their facilities.

We hold a 91% ownership interest in PE Op Co. (formerly, New PE Holdco LLC), the owner of each of the plant holding companies, or the Plant Owners, that collectively own the Pacific Ethanol Plants. We operate and maintain the Pacific Ethanol Plants under the terms of an asset management agreement with the Plant Owners, including supplying all goods and materials necessary to operate and maintain each Pacific Ethanol Plant. In operating the Pacific Ethanol Plants, we direct the production process to obtain optimal production yields, lower costs by leveraging our infrastructure, enter into risk management agreements such as insurance policies and manage commodity risk practices.

We market ethanol and its co-products, including WDG and corn oil, produced by the Pacific Ethanol Plants under the terms of separate marketing agreements with the Plant Owners. The marketing agreements provide us with the absolute discretion to solicit, negotiate, administer (including payment collection), enforce and execute ethanol and co-product sales agreements with any third party.

The Pacific Ethanol Plants are comprised of the four facilities described immediately below and have an aggregate annual production capacity of up to 200 million gallons. We commenced production at our Madera, California facility on April 30, 2014 and reached full capacity in the second quarter of 2014.

Facility Name	Facility Location	Estimated Annual Capacity (gallons)	Current Operating Status
Magic Valley	Burley, ID	60,000,000	Operating
Columbia	Boardman, OR	40,000,000	Operating
Stockton	Stockton, CA	60,000,000	Operating
Madera	Madera, CA	40,000,000	Operating

We earn fees as follows under our asset management and other agreements with PE Op Co. and the Plant Owners:

ethanol marketing fees of approximately 1% of the net sales price, but not less than $0.015 per gallon and not more than $0.0225 per gallon;

corn procurement and handling fees of $0.045 per bushel;

WDG, syrup and corn oil fees of 5% of the third-party purchase price, excluding freight, but not less than $2.00 per ton and not more than $3.50 per ton; and

asset management fees of $75,000 per month for each operating facility and $40,000 per month for each idled facility.

We intend to advance our position as the leading producer and marketer of low-carbon renewable fuels in the Western United States, in part by expanding our relationships with customers and third-party ethanol producers to market higher volumes of ethanol and by expanding the market for ethanol by continuing to work with state governments to encourage the adoption of policies and standards that promote ethanol as a transportation fuel and fuel additive.

Current Initiatives and Outlook

Current production margins remain strong but have contracted since their peak near the end of the first quarter. The Pacific Ethanol Plants continue to operate profitably and contribute positively to our overall financial position. We expect a balanced supply and demand for ethanol supportive of strong ethanol margins over the coming months and into 2015, in part due to stronger demand for exports from the United States, and ethanol blend rates at least at current levels through the balance of 2014. Due to recent declines in WDG prices and the cost of corn, we expect our co-product returns as a percentage of our cost of corn to decline from current levels during the coming months.

Ethanol prices in the Western United States have typically been $0.20 per gallon higher than in the Midwest due to the freight costs of delivering ethanol from Midwest production facilities. From October 2013 through April 2014, however, ethanol prices in the Western United States have averaged $0.40 per gallon higher than ethanol prices in the Midwest due to rail logistics challenges and weather conditions during the winter which constrained the flow of ethanol and co-products from the Midwest to the markets in which we operate. These premiums have normalized somewhat in the second quarter and through the filing of this report.

From 2010 through 2013, we issued in various financing transactions warrants to purchase shares of our common stock. The warrants were initially recorded at their fair values, which are adjusted quarterly, generally resulting in non-cash expenses or income if the market price of our common stock increases or decreases, respectively, during the period. Due to the substantial increase in the market price of our common stock in the first quarter of 2014 and because the exercise prices of these warrants were, as of March 31, 2014 and June 30, 2014, well below the market price of our common stock, the fair values of the warrants and the related non-cash expenses were significantly higher in the first quarter and first six months of 2014 than in the comparable prior periods in 2013, which resulted in unusually large non-cash expenses for those periods. These fair value adjustments will continue in future periods until all of our warrants are exercised or expire. These adjustments will generally reduce our net income or increase our net loss if the market price of our common stock increases on a quarter over quarter basis. Conversely, the adjustments will generally increase our net income or reduce our net loss if the market price of our common stock declines on a quarter over quarter basis. Since June 30, 2014, we have processed warrant exercises for approximately 2.7 million shares of our common stock. We expect that these warrant exercises will reduce our GAAP earnings volatility in future quarters as the amount of warrants marked to fair value has declined significantly.

We began producing and selling corn oil at our Magic Valley and Stockton facilities in June 2013 and October 2013, respectively, allowing us to diversify our revenue and providing immediate incremental gross profit. We are currently producing corn oil in meaningful amounts at both facilities and plan to complete the implementation of corn oil production technology at the remaining two Pacific Ethanol Plants by early 2015. We have also implemented advanced grinding technologies at our Magic Valley and Stockton facilities and will evaluate when and to what extent these technologies should be implemented at the remaining two Pacific Ethanol Plants.

We continue to focus on increasing operating efficiencies and improving yields at the Pacific Ethanol Plants. To this end, we installed yield-enhancing Cellunators^TM technology at our Stockton facility, allowing us to increase yields by increasing available starch for conversion. This technology also may allow us to produce cellulosic corn ethanol. Based on current production margins, each 1% improvement in production yields results in approximately $3.0 million in additional annual gross profit when operating at our full production capacity of 200 million gallons. We have approved a capital expenditure budget to reinvest up to $16.0 million in the Pacific Ethanol Plants over the next six months to further improve efficiencies, diversify feedstock and implement our advanced biofuels initiatives. Our goal with these investments is to achieve a 5 to 6 cent per gallon improvement in annual operating earnings, which equals $10.0 million to $12.0 million in additional annual operating earnings.

The regulatory environment continues to support the long-term demand for renewable fuels. California’s Low-Carbon Fuel Standard requires refiners to reduce the carbon intensity of their fuels by 10% between 2011 and 2020, which we believe is an aggressive requirement that will necessitate a significant amount of low-carbon fuel to displace gasoline in the California fuel supply. We continue to reduce energy use at the Pacific Ethanol Plants to lower the carbon intensity of our ethanol. We believe that we have a significant advantage in the marketplace because we produce among the lowest-carbon ethanol commercially produced in the United States which enables us to capture a premium for ethanol we produce and sell in the California market.

We also continue to diversify our feedstock by using a blend of corn, sorghum and beet sugar, which reduces feedstock costs and reduces the carbon output of ethanol we produce. Using beet sugar as feedstock, we were able to reduce our material costs by approximately $1.7 million and $3.1 million for the three and six months ended June 30, 2014, respectively. We expect to continue to use beet sugar throughout 2014 at levels approximating 15% of total feedstock at our Magic Valley and Columbia facilities. The United States Department of Agriculture anticipates a record 2013-2014 corn crop, but we are uncertain how the new crop will affect our ethanol production and intend to operate the Pacific Ethanol Plants with flexibility in anticipation of the new crop.

We recently were awarded a $3.0 million matching grant from the California Energy Commission to develop a sorghum feedstock program collaboratively with Chromatin, Inc., California State University, Fresno’s Center for Irrigation Technology and the Kearney Agricultural Research and Extension Center. This undertaking also includes the California In-State Sorghum Program to support a lasting expansion in California’s ability to produce low-carbon ethanol from in-state feedstock that meets both the renewable fuel and greenhouse gas reduction goals stipulated under the federal Renewable Fuel Standard and California’s Low-Carbon Fuel Standard.

We continue to pursue production of advanced biofuels at the Pacific Ethanol Plants. To this end, we are in the project development phase with Sweetwater Energy to acquire cellulosic industrial sugars. We expect this project will take at least two years. We are also working with Cellunators^TMtechnology to enable the release of cellulosic sugars from corn kernel fibers which, when released through an appropriate enzyme for commercial production, will allow us to produce cellulosic ethanol for up to 2.0% of our overall production at a plant that uses the technology. We are also running a pilot program for anaerobic digestion at our Stockton facility to substitute biogas for natural gas for the production of advanced biofuels. In addition, our Magic Valley plant is well situated to add new facilities enabling ethanol production from wheat straw and we are evaluating the feasibility of a cellulosic project of this nature at this facility. Finally, we are analyzing various co-generation configurations, particularly at our California plants where energy prices are high and we receive a low-carbon premium for the ethanol we produce and sell into the California market.

Our goals for the remainder of 2014 include further improving operating efficiencies and improving yields at the Pacific Ethanol Plants and continuing to increase the value of our produced ethanol by further reducing its carbon intensity, all of which are directed at supporting sustained profitable growth.

Critical Accounting Policies

The preparation of our financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America, requires us to make judgments and estimates that may have a significant impact upon the portrayal of our financial condition and results of operations. We believe that of our significant accounting policies, the following require estimates and assumptions that require complex, subjective judgments by management that can materially impact the portrayal of our financial condition and results of operations: revenue recognition; warrants carried at fair value and conversion features; impairment of long-lived and intangible assets; and allowance for doubtful accounts. These significant accounting principles are more fully described in “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Policies” in our Annual Report on Form 10-K for the year ended December 31, 2013.

Results of Operations

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

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

	Three Months Ended June 30				Percentage			Six Months Ended June 30,				Percentage
	2014		2013		Variance			2014		2013		Variance
Production gallons sold (in millions)		46.5		36.8		26.4%			86.3		72.1		19.7%
Third party gallons sold (in millions)		85.7		64.4		33.1%			158.6		129.9		22.1%
Total gallons sold (in millions)		132.2		101.2		30.6%			244.9		202.0		21.2%
Average sales price per gallon	$	2.78	$	2.79		(0.4%	)	$	2.75	$	2.69		2.2%
Corn cost per bushel – CBOT equivalent	$	4.84	$	6.55		(26.1%	)	$	4.67	$	6.85		(31.8%	)
Average basis ⁽¹⁾	$	1.13	$	1.41		(19.9%	)	$	1.20	$	1.30		(7.7%	)
Delivered cost of corn	$	5.97	$	7.96		(25.0%	)	$	5.87	$	8.15		(28.0%	)
Co-product revenues as % of delivered cost of corn⁽²⁾		36.5%		27.6%		32.2%			35.3%		27.9%		26.5%
Average CBOT ethanol price per gallon	$	2.25	$	2.53		(11.1%	)	$	2.23	$	2.47		(9.7%	)
Average CBOT corn price per bushel	$	4.79	$	6.61		(27.5%	)	$	4.66	$	6.88		(32.3%	)

__________

	(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 are yield based on sales of co-products, including WDG and corn oil, generated from ethanol we produced.

Net Sales, Cost of Goods Sold and Gross Profit

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

	Three Months Ended June 30,				Variance in				Six Months Ended June 30,				Variance in
	2014		2013		Dollars		Percent		2014		2013		Dollars		Percent

Net sales	$	321,144	$	233,808	$	87,336		37.4%	$	575,687	$	459,267	$	116,420		25.3%
Cost of goods sold		287,568		226,843		60,725		26.8%		503,566		451,456		52,110		11.5%
Gross profit	$	33,576	$	6,965	$	26,611		382.1%	$	72,121	$	7,811	$	64,310		823.3%
Percentage of net sales		10.5%		3.0%						12.5%		1.7%

Net Sales

The increase in our net sales for the three and six months ended June 30, 2014 as compared to the same periods in 2013 was primarily due to an increase in our total gallons sold.

Our total volume of ethanol gallons sold increased by 31.0 million gallons, or 31%, to 132.2 million gallons and by 42.9 million gallons, or 21%, to 244.9 million gallons for the three and six months ended June 30, 2014 as compared to 101.2 million gallons and 202.0 million gallons for the same periods in 2013, respectively. We increased both production and third party gallons sold for the three and six months ended June 30, 2014 as compared to the same periods in 2013. The increases in our production gallons and third party gallons sold are primarily due to increased production rates at the Pacific Ethanol Plants and third party supplier plants, respectively, including as a result of our recent restart of production at our Madera plant. We and our third party suppliers increased production rates due to higher industry-wide corn crush margins resulting from lower corn costs and higher ethanol prices due to tighter ethanol supply relative to demand. In addition, our third party sales increased due to expanding our customer base and sales within our various locations.

Our average sales price per gallon was essentially flat at $2.78 for the three months ended June 30, 2014 compared to our average sales price per gallon of $2.79 for the same period in 2013. In contrast, the average Chicago Board of Trade, or CBOT, ethanol price per gallon declined 11% to $2.25 for the three months ended June 30, 2014 compared to an average CBOT sales price per gallon of $2.53 for the same period in 2013.

Our average sales price per gallon increased by 2% to $2.75 for the six months ended June 30, 2014 compared to our average sales price per gallon of $2.69 for the same period in 2013. In contrast, the average CBOT ethanol price per gallon declined 10% to $2.23 for the six months ended June 30, 2014 compared to an average CBOT sales price per gallon of $2.47 for the same period in 2013.

This disparity between our ethanol sales price per gallon and the CBOT average reflects both the additional basis costs for West Coast delivery of ethanol as well as the premiums we receive by selling lower-carbon intensity ethanol in the Western United States. Ethanol prices in the Western United States were also higher than ethanol prices in the Midwest due to weather conditions in the first quarter of 2014 and ongoing rail logistics challenges which constrained the flow of ethanol and co-products from the Midwest to the markets in which we operate.

Cost of Goods Sold and Gross Profit

Our gross profit improved significantly to $33.6 million for the three months ended June 30, 2014 from $7.0 million for the same period in 2013. Our gross margin also improved significantly to 10.5% for the three months ended June 30, 2014 from 3.0% for the same period in 2013. Our gross profit improved to $72.1 million for the six months ended June 30, 2014 from $7.8 million for the same period in 2013. Our gross margin improved to 12.5% for the six months ended June 30, 2014 from 1.7% for the same period in 2013. Our gross profit and gross margins increased for these periods primarily due to significantly improved crush and commodity margins and higher production yields realized at the Pacific Ethanol Plants, predominantly related to lower corn costs and tighter ethanol supply relative to demand as well as higher ethanol prices in the Western United States due to weather conditions in the first quarter of 2014 and rail logistics challenges which constrained the flow of ethanol and co-products from the Midwest to the markets in which we operate. Crush and commodity margins reflect ethanol and co-product sales prices relative to ethanol production inputs such as corn and natural gas. Our ongoing plant efficiency and yield improvement initiatives also positively impacted our margins.

Selling, General and Administrative Expenses

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

	Three Months Ended June 30,				Variance in				Six Months Ended June 30,				Variance in
	2014		2013		Dollars		Percent		2014		2013		Dollars		Percent
Selling, general and administrative expenses	$	4,315	$	3,133	$	1,182		37.7%	$	7,985	$	7,138	$	847		11.9%
Percentage of net sales		1.3%		1.3%						1.4%		1.6%

Our SG&A increased $1.2 million to $4.3 million for the three months ended June 30, 2014 as compared to $3.1 million for the same period in 2013, but remained flat as a percentage of net sales for the three months ended June 30, 2014 as compared to the same period in 2013. The increase in SG&A is primarily due to the following factors:

an increase in compensation costs of $0.6 million due to incentive compensation tied to our profitability and general annual pay increases; and

an increase in professional fees of $0.4 million due to increased corporate activity.

Our SG&A increased $0.9 million to $8.0 million for the six months ended June 30, 2014 as compared to $7.1 million for the same period in 2013, but declined as a percentage of net sales for the six months ended June 30, 2014 as compared to the same period in 2013. The increase in SG&A is primarily due to an increase in compensation costs of $1.0 million due to incentive compensation tied to our profitability and general annual pay increases.

At current levels of operation, we expect our SG&A expense run rate will be approximately $4.0 million per quarter through the end of 2014.

Fair Value Adjustments and Warrant Inducements

The following table presents our fair value adjustments and warrant inducements in dollars and as a percentage of net sales (in thousands, except percentages):

	Three Months Ended June 30,				Variance in						Six Months Ended June 30,					Variance in
	2014		2013		Dollars			Percent			2014			2013		Dollars			Percent
Fair value adjustments and warrant inducements	$	485	$	1,437	$	(952	)		(66.2%	)	$	(35,359	)	$	745	$	(36,104	)	NM
Percentage of net sales		0.2%		0.6%								(6.1%	)		0.2%

We issued certain warrants in various financing transactions from 2010 through 2013. These warrants were initially recorded at fair value and are adjusted quarterly. As a result of quarterly adjustments to their fair values and warrant inducements, we recorded income of $0.5 million and $1.4 million for the three months ended June 30, 2014 and 2013, respectively, and we recorded an expense of $35.4 million and income of $0.7 million for the six months ended June 30, 2014 and 2013, respectively.

These changes in fair value are primarily due to the increased number of warrants issued in the three months ended March 31, 2013 and the volatility in the market price of our common stock from period to period. The substantial change in fair value for the six months ended June 30, 2014 occurred because the exercise prices of our warrants were, as of June 30, 2014, well below the market price of our common stock. At December 31, 2013, the market price of our common stock was $5.09 per share and our outstanding warrants had a weighted-average exercise price of $7.27 per share. At March 31, 2014, the market price of our common stock had increased to $15.58 per share, and our outstanding warrants were in-the-money and had significant intrinsic value. At June 30, 2014, the market price of our common stock had declined slightly from the prior quarter to $15.29.

We paid an aggregate of $0.8 million in cash to certain warrant holders as an inducement to exercise their warrants and recorded an expense of $0.8 million for each of the three and six months ended June 30, 2014 and 2013.

These fair value adjustments will continue in future periods until all of our warrants are exercised or expire. These adjustments will generally reduce our net income or increase our net loss if the market price of our common stock increases on a quarter over quarter basis. Conversely, the adjustments will generally increase our net income or reduce our net loss if the market price of our common stock declines on a quarter over quarter basis.

Since June 30, 2014, we have processed warrant exercises for approximately 2.7 million shares of our common stock for approximately $20.9 million in cash. We expect that these exercises will reduce our GAAP earnings volatility in future quarters as the amount of warrants marked to fair value has declined significantly.

Interest Expense, net

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

	Three Months Ended June 30,				Variance in						Six Months Ended June 30,				Variance in
	2014		2013		Dollars			Percent			2014		2013		Dollars			Percent
Interest expense, net	$	2,886	$	3,972	$	(1,086	)		(27.3%	)	$	7,237	$	7,453	$	(216	)		(2.9%	)
Percentage of net sales		0.9%		1.7%								1.3%		1.6%

Interest expense, net declined by $1.1 million to $2.9 million for the three months ended June 30, 2014 from $4.0 million for the same period in 2013. Interest expense, net declined by $0.2 million to $7.2 million for the six months ended June 30, 2014 from $7.4 million for the same period in 2013. The decrease in interest expense, net for these periods is primarily due to decreased average debt balances, partially offset by accelerations of debt discount and deferred financing fees of an aggregate $0.9 million and $2.5 million for the three and six months ended June 30, 2014, respectively, due to the early retirement of the Plant Owners’ debt and our senior unsecured notes. At current debt balances, we expect our ongoing interest expense will be less than $1.5 million quarterly.

Gain (Loss) on Extinguishments of Debt

The following table presents our gain (loss) on extinguishments of debt in dollars and as a percentage of net sales (in thousands, except percentages):

	Three Months Ended June 30,						Variance in				Six Months Ended June 30,					Variance in
	2014			2013			Dollars			Percent	2014			2013		Dollars			Percent
Gain (loss) on extinguishments of debt	$	(2,363	)	$	(39	)	$	(2,324	)	NM	$	(2,363	)	$	778	$	(3,141	)	NM
Percentage of net sales		(0.7	)%		—%							(0.4%	)		0.2%

For the three and six months ended June 30, 2014, we extinguished certain PE Op Co. debt by paying $2.3 million in cash in excess of the amount of the debt, and as such, recorded a loss on extinguishments of debt. For the three and six months ended June 30, 2013, we extinguished PE Op Co. debt by paying $0.9 million and $1.8 million in cash, respectively, less than the amount of the debt, and as such recorded gains on extinguishments of debt. Further, in the three and six months ended June 30, 2013, we recorded a loss of $1.0 million related to conversions of our convertible notes into shares of our common stock at a discount to prevailing market prices.

We retired a total of $31.7 million and $64.8 million in debt in the three and six months ended June 30, 2014, eliminating all parent level debt and reducing our consolidated third-party debt at the Pacific Ethanol Plant level to $17.0 million.

Other Expense, net

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

	Three Months Ended June 30,				Variance in				Six Months Ended June 30,				Variance in
	2014		2013		Dollars		Percent		2014		2013		Dollars		Percent
Other expense, net	$	335	$	128	$	207		161.7%	$	562	$	215	$	347		161.4%
Percentage of net sales		0.1%		0.1%						0.1%		—%

Other expense, net increased by $0.2 million to $0.3 million for the three months ended June 30, 2014 from $0.1 million for the same period in 2013. Other expense, net increased by $0.3 million to $0.6 million for the six months ended June 30, 2014 from $0.2 million for the same period in 2013. These increases in other expense, net are primarily due to expenditures related to nonoperational items at the Pacific Ethanol Plants.

Provision for Income Taxes

The following table presents our provision for income taxes in dollars and as a percentage of net sales (in thousands, except percentages):

	Three Months Ended June 30,				Variance in			Six Months Ended June 30,				Variance in
	2014		2013		Dollars		Percent	2014		2013		Dollars		Percent
Provision for income taxes	$	7,196	$	–	$	7,196	NM	$	10,466	$	–	$	10,466	NM
Percentage of net sales		2.2%		—%					1.8%		—%

For the three and six months ended June 30, 2014, we generated income subject to income tax. We applied a portion of our net operating loss carryforwards to our potential taxable income and as a result, we recorded a gross provision for income taxes of $18.5 million. Further, we reversed $8.0 million of our valuation allowance against our net tax assets, resulting in a net provision for income taxes of $10.5 million for the six months ended June 30, 2014. Our remaining net operating loss carryforwards may be limited on an annual basis for the remainder of the year.

Net (Income) Loss Attributed to Noncontrolling Interests

The following table presents the portion of our net (income) loss attributed to noncontrolling interests in dollars and as a percentage of net sales (in thousands, except percentages):

	Three Months Ended June 30,						Variance in					Six Months Ended June 30,					Variance in
	2014			2013			Dollars			Percent		2014			2013		Dollars			Percent
Net (income) loss attributed to noncontrolling interests	$	(1,394	)	$	(79	)	$	(1,315	)		1,664.6%	$	(3,403	)	$	1,069	$	(4,472	)	NM
Percentage of net sales		(0.4%	)		—%								(0.6%	)		0.2%

Net (income) loss attributed to noncontrolling interests relates to our consolidated treatment of PE Op Co. For the three and six months ended June 30, 2014 and 2013, we consolidated the entire income statement of PE Op Co. However, because we owned only 91% and 85% of PE Op Co. for the three and six months ended June 30, 2014 and 2013, respectively, we reduced our consolidated net income (loss) for the noncontrolling interests, which were the ownership interests that we did not own. The increases in net income attributed to noncontrolling interests for the periods are primarily due to higher operating income from significantly improved commodity margins, much of which was generated at the Pacific Ethanol Plant level.

Net Income (Loss) Attributed to Pacific Ethanol

The following table presents our net income (loss) attributed to Pacific Ethanol in dollars and as a percentage of net sales (in thousands, except percentages):

	Three Months Ended June 30,				Variance in				Six Months Ended June 30,					Variance in
	2014		2013		Dollars		Percent		2014		2013			Dollars		Percent
Net income (loss) attributed to Pacific Ethanol	$	15,572	$	1,051	$	14,521		1,381.6%	$	4,746	$	(4,403	)	$	9,149	NM
Percentage of net sales		4.8%		0.4%						0.8%		(1.0%	)

Net income (loss) attributed to Pacific Ethanol increased substantially during the three and six months ended June 30, 2014 as compared to the same periods in 2013, primarily due to significantly improved crush and commodity margins and our increased ownership interest in PE Op Co., which were partially offset, for the six months ended June 30, 2014, by our fair value adjustments during that period.

Preferred Stock Dividends and Income (Loss) Available to Common Stockholders

The following table presents our preferred stock dividends in dollars for our Series B Cumulative Convertible Preferred Stock, or Series B Preferred Stock, these preferred stock dividends as a percentage of net sales, and our income (loss) available to common stockholders in dollars and as a percentage of net sales (in thousands, except percentages):

	Three Months Ended June 30,				Variance in				Six Months Ended June 30,					Variance in
	2014		2013		Dollars		Percent		2014		2013			Dollars		Percent
Preferred stock dividends	$	315	$	315	$	–		–%	$	627	$	627		$	–		–%
Percentage of net sales		0.1%		0.1%						0.1%		0.1%
Income (loss) available to common stockholders	$	15,257	$	736	$	14,521		1,973.0%	$	4,119	$	(5,030	)	$	9,149	NM
Percentage of net sales		4.8%		0.3%						0.7%		(1.1%	)

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 cash dividends on our Series B Preferred Stock in the aggregate amount of $0.3 million for the three months ended June 30, 2014 and 2013, and $0.6 million for the six months ended June 30, 2014 and 2013.

Liquidity and Capital Resources

During the six months ended June 30, 2014, we funded our operations primarily from cash on hand, cash flow from operations, proceeds from an equity offering, warrant exercises and borrowings under our credit facilities. Funds generated from these sources were also used to make debt payments, including prepayments, in the amount of $64.8 million, eliminating all parent level debt and reducing our consolidated third-party debt at the Pacific Ethanol Plant level to $17.0 million. In addition, since June 30, 2014, we processed warrant exercises for approximately 2.7 million shares of our common stock for approximately $20.9 million in cash.

Our current available capital resources consist of cash on hand of approximately $52.4 million and amounts available for borrowing under Kinergy’s credit facility. In addition, the Plant Owners have credit facilities for use in the operations of the Pacific Ethanol Plants. We expect that our future available capital resources will consist primarily of our remaining cash balances, amounts available for borrowing, if any, under Kinergy’s credit facility, cash generated from Kinergy’s ethanol marketing business, fees paid under our asset management agreement relating to our operation of the Pacific Ethanol Plants, proceeds from warrant exercises and dividends, if any, in respect of our ownership interest in PE Op Co.

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 working capital and capital expenditure requirements for at least the next twelve months.

Quantitative Quarter-End Liquidity Status

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

	June 30, 2014		December 31, 2013		Variance
Cash and cash equivalents	$	25,923	$	5,151		403.3%
Current assets	$	112,413	$	79,377		41.6%
Current liabilities	$	33,280	$	28,216		17.9%
Notes payable, current portion	$	–	$	750		(100.0%	)
Notes payable, noncurrent portion	$	38,374	$	98,408		(61.0%	)
Working capital	$	79,133	$	51,161		54.7%
Working capital ratio		3.38		2.81		20.3%

Change in Working Capital and Cash Flows

Working capital increased to $79.1 million at June 30, 2014 from $51.2 million at December 31, 2013 as a result of an increase in current assets of $33.0 million, which was partially offset by an increase in current liabilities of $5.1 million.

Current assets increased primarily due to an increase in cash and cash equivalents of $20.8 million, accounts receivable of $7.8 million predominantly due to a higher volume of production gallons sold at higher ethanol sales prices, an increase in inventories of $4.2 million, and an increase in prepaid inventories of $2.5 million, which were partially offset by a decrease in other current assets of $2.2 million. Cash and cash equivalents increased primarily as a result of an equity offering in April 2014 in which we raised net proceeds of $26.1 million and cash exercises of our warrants in the aggregate amount of $18.2 million. Current liabilities increased primarily due to increases in trade accounts payable of $5.5 million resulting from higher sales volumes, and an increase in accrued liabilities of $4.6 million, due to income taxes payable from profitable operations, which were partially offset by a decrease in other current liabilities of $4.3 million, and a decrease in current portion of our long-term debt of $0.8 million.

Cash provided by operating activities of $51.3 million resulted primarily from consolidated net income of $8.1 million, non-cash fair value adjustments of $34.6 million, depreciation and amortization of $6.4 million, increases in accounts payable and accrued expenses of $5.3 million due to higher sales volumes, decreases in prepaid expenses and other assets of $3.1 million, changes in deferred income taxes of $2.9 million, gain on extinguishments of debt of $2.4 million and amortization of debt discount of $1.8 million, which were partially offset by increases in accounts receivable of $7.7 million, increases in inventories of $4.2 million due to higher sales volumes and increases in prepaid inventory of $2.5 million.

Cash used in our investing activities of $6.5 million resulted from additions to property and equipment.

Cash used in financing activities of $24.0 million resulted from repayments of our senior unsecured notes and the Plant Owners’ borrowings of $66.4 million, our related party note payable of $0.8 million, principal payments on capital leases of $2.5 million and cash payment of dividends in respect of our Series B Preferred Stock of $0.6 million, which were partially offset by the proceeds from our equity offering in April 2014 of $26.1 million, cash exercises of our warrants in the aggregate amount of $18.2 million and net proceeds from borrowings under Kinergy’s line of credit of $2.3 million.

Kinergy Operating Line of Credit

Kinergy maintains an operating line of credit for an aggregate amount of up to $30.0 million, with an optional accordion feature for up to an additional $10.0 million. The credit facility expires on December 31, 2015. 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 between 2.25% and 3.25%. The credit facility’s monthly unused line fee is 0.50% of the amount by which the maximum credit under the facility exceeds the average daily principal balance. 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 $1.0 million per fiscal quarter in 2014 and $1.1 million per fiscal quarter in 2015.

The credit facility also includes the accounts receivable of Pacific Ag. Products, LLC, or PAP, one of our indirect wholly-owned subsidiaries, 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 the extent that quarterly payments would result in PAP recording less than $0.1 million of net income in the quarter.

Kinergy and PAP are collectively required to generate aggregate earnings before interest, taxes, depreciation and amortization, or EBITDA, of $0.5 million, measured at the end of each calendar month, for each three calendar month period and EBITDA of $1.3 million, measured at the end of each calendar month, for each six calendar month period. Further, for all monthly periods, Kinergy and PAP must collectively 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 any additional indebtedness (other than specific intercompany indebtedness) or making any capital expenditures in excess of $0.1 million absent the lender’s prior consent. 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.

The following table summarizes Kinergy’s financial covenants and actual results for the periods presented (dollars in thousands):

	Three Months Ended June 30,				Years Ended December 31,
	2014		2013		2013		2012

EBITDA Requirement – Three Months	$	500	$	450	$	450	$	450
Actual	$	1,922	$	1,231	$	3,252	$	1,165
Excess	$	1,422	$	781	$	2,802	$	715

EBITDA Requirement – Six Months	$	1,300	$	1,100	$	1,100	$	1,100
Actual	$	10,138	$	3,997	$	4,131	$	3,282
Excess	$	8,838	$	2,897	$	3,031	$	2,182

Fixed Charge Coverage Ratio Requirement		2.00		2.00		2.00		2.00
Actual		14.54		19.00		8.64		8.84
Excess		12.54		17.00		6.64		6.84

Pacific Ethanol has guaranteed all of Kinergy’s obligations under the credit facility. As of June 30, 2014, Kinergy had an available borrowing base under the credit facility of $8.6 million and an outstanding balance of $21.4 million.

Plant Owners’ Term Debt and Operating Lines of Credit

The Plant Owners’ debt as of June 30, 2014 consisted of a $32.5 million tranche A-1 term loan and a $26.3 million tranche A-2 term loan. Pacific Ethanol, Inc. holds $41.8 million of these term loans, which are eliminated in consolidation. The term debt requires monthly interest payments at a floating rate equal to the three-month LIBOR or the Prime Rate of interest, at the Plant Owners’ election, plus 10.0%. The revolving credit facilities require monthly interest payments at a floating rate equal to the three-month LIBOR or the Prime Rate of interest, at the Plant Owners’ election, plus 10.0% and 5.5% for the $19.5 million and $15.0 million facilities, respectively. At June 30, 2014, the average interest rate was approximately 11.0%. Repayments of principal are based on available free cash flow of the Plant Owners, until maturity, when all principal amounts are due.

As of June 30, 2014, the Plant Owners had no outstanding principal balances on these revolving credit facilities and an aggregate borrowing availability of $34.5 million.

All of the term loans and revolving credit facilities represent permanent financing and are secured by a perfected, first-priority security interest in all of the assets, including inventories and all rights, title and interest in all tangible and intangible assets, of the Plant Owners. The Plant Owners’ creditors do not have recourse to Pacific Ethanol, Inc.

Pacific Ethanol Debt

Senior Unsecured Notes

On January 11, 2013 we issued and sold $22.2 million in aggregate principal amount of senior unsecured notes and warrants to purchase an aggregate of 1.7 million shares of our common stock for aggregate net proceeds of $22.1 million. The warrants have an exercise price of $6.32 per share and expire in January 2018. As of the filing of this report, we have fully repaid these notes.

Note Payable to Related Party

We repaid in cash a note payable to our Chief Executive Officer totaling $0.8 million on March 31, 2014.

Effects of Inflation

The impact of inflation was not significant to our financial condition or results of operations for the three and six months ended June 30, 2014 and 2013.

Impact of New Accounting Pronouncements

None.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.

Not applicable.

ITEM 4. CONTROLS AND PROCEDURES.

Evaluation of Disclosure Controls and Procedures

We conducted an evaluation under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures. The term “disclosure controls and procedures,” as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended, or Exchange Act, means controls and other procedures of a company that are designed to ensure that information required to be disclosed by the company in the reports it files or submits under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the Securities and Exchange Commission’s rules and forms. Disclosure controls and procedures also include, without limitation, controls and procedures designed to ensure that information required to be disclosed by a company in the reports that it files or submits under the Exchange Act is accumulated and communicated to the company’s management, including its principal executive and principal financial officers, or persons performing similar functions, as appropriate, to allow timely decisions regarding required disclosure. Based on this evaluation, our Chief Executive Officer and Chief Financial Officer concluded as of June 30, 2014 that our disclosure controls and procedures were effective at a reasonable assurance level.

Changes in Internal Control over Financial Reporting

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

Inherent Limitations on the Effectiveness of Controls

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

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

PART II - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS.

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

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 alleges 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 we have an interest, including Pacific Ethanol Stockton LLC (“PE Stockton”), located in Stockton, California. The complaint seeks preliminary and permanent injunctions against us, 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 attorney’s fees. We have since answered the complaint and counterclaimed that the patent claims at issue, as well as the claims in several related patents, are invalid and unenforceable and that we are 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 of our subsidiaries: PE Stockton and Pacific Ethanol Magic Valley, LLC (“PE Magic Valley”). The claims are similar to those filed against Pacific Ethanol, Inc. in May 2013. These two cases, currently pending in the United States District Court for the Eastern District of California and United States District Court for the Eastern District of Idaho, respectively, have been 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. is pending, in accordance with a Conditional Transfer Order issued by the Judicial Panel on Multidistrict Litigation on March 27, 2014. 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. Pacific Ethanol, Inc., together with PE Stockton and PE Magic Valley, are vigorously presenting defenses that include noninfringement, unenforceability, and invalidity of each of the patents at issue. Discovery in all three cases closes September 23, 2014.

ITEM 1A. RISK FACTORS.

Our operations and financial results are subject to various risks and uncertainties, including those described below, which could adversely affect our business, financial condition, results of operations, cash flows, and the market price of our common stock.

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 2013 and 2012, we incurred consolidated net losses of approximately $1.2 million and $43.4 million, respectively, and in 2012 incurred negative operating cash flow of $20.8 million. We may incur losses and negative operating cash flow in the future. We expect to rely on cash on hand and cash, if any, generated from our operations and from future financing activities, 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, WDG 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, WDG 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, WDG 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, WDG 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, WDG 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, WDG or other ethanol co-products.

Over the past several years, the spread between ethanol and corn prices has fluctuated significantly. Corn crush margins, measured by the spread between ethanol and corn prices, continue to remain strong, although they have contracted since their historic peak in March 2014. 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, WDG and other ethanol co-products could decline below the marginal cost of production, which may force us to suspend production of ethanol, WDG and ethanol co-products at some or all of the Pacific Ethanol Plants.

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

We believe that the most significant factor influencing the price of ethanol has been the substantial increase in ethanol production in recent years. Domestic ethanol production capacity has increased steadily from an annualized rate of 1.5 billion gallons per year in January 1999 to 14.9 billion gallons in 2013 according to the Renewable Fuel Association. In addition, due to significantly improved ethanol production margins, we anticipate that owners of idle ethanol production facilities, many of which were idled due to poor production margins, will restart operations, thereby resulting more abundant ethanol supplies and inventories. Any increase in the demand for ethanol may not be commensurate with increases in the supply of ethanol, thus leading to lower ethanol prices. Also, demand for ethanol could be impaired due to a number of factors, including regulatory developments and reduced United States gasoline consumption. Reduced gasoline consumption has occurred in the past and could occur in the future as a result of increased gasoline or oil prices. 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 Chicago Board of Trade, or CBOT, ranged from $1.61 to $2.74 per gallon during 2013 and corn prices, as reported by the CBOT, ranged from $4.12 to $7.41 per bushel during 2013. Recently, ethanol prices as reported by the CBOT have declined from $3.46 at March 31, 2014 to $2.09 at July 31, 2014. Fluctuations in the market price of ethanol may cause our profitability or losses to fluctuate significantly.

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

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

Disruptions in ethanol production 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 the Pacific Ethanol Plants and other considerations related to production efficiencies, the Pacific Ethanol Plants depend on just-in-time delivery of corn. The production of ethanol also requires a significant and uninterrupted supply of other raw materials and energy, primarily water, electricity and natural gas. The prices of electricity and natural gas have fluctuated significantly in the past and may fluctuate significantly in the future. Local water, electricity and gas utilities may not be able to reliably supply the water, electricity and natural gas that the Pacific Ethanol Plants will need or may not be able to supply those resources on acceptable terms. Any disruptions in the ethanol production 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 may require the Pacific Ethanol Plants to halt production which could have a material adverse effect on our business, results of operations and financial condition.

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

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

Operational difficulties at the Pacific Ethanol Plants could negatively impact sales volumes and could cause us to incur substantial losses.

Operations at the Pacific Ethanol 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. Insurance obtained by the Pacific Ethanol Plants may not be adequate to fully cover the potential operational hazards described above or the Pacific Ethanol Plants may not be able to renew this insurance on commercially reasonable terms or at all.

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

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 United States Environmental Protection Agency, or EPA, has implemented a Renewable Fuel Standard, or 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. The national RFS minimum requirement of 13.8 billion gallons of conventional biofuels (or ethanol derived from corn starch) to be consumed in the United States in 2013 reflected approximated current domestic production levels of such ethanol. Future demand of ethanol will be largely dependent upon incentives to blend ethanol into motor fuels, including the relative price of gasoline versus ethanol, the relative octane value of ethanol, constraints in the ability of vehicles to use higher ethanol blends, the national RFS, and other applicable environmental requirements. Any significant increase in production capacity above the national RFS minimum requirements may have an adverse impact on ethanol prices.

Legislation aimed at reducing or eliminating the renewable fuel use required by the national RFS has been introduced in the United States Congress. On April 10, 2013 the Renewable Fuel Standard Elimination Act was introduced as H.R. 1461. The bill is targeted to repeal the national RFS. Also introduced on April 10, 2013 was the RFS Reform Bill, H.R. 1462, which would prohibit more than ten percent ethanol in gasoline and reduce the national RFS mandated volume of renewable fuel. On May 14, 2013, the Domestic Alternatives Fuels Act of 2013 was introduced in the United States House of Representatives as H.R. 1959 to allow ethanol produced from natural gas to be used to meet the national RFS mandate. These bills were assigned to a congressional committee, which will consider them before possibly sending any on to the House or Senate as a whole. Our operations could be adversely impacted if the RFS Reform Act of 2013, the RFS Elimination Act of 2013, or other legislation is enacted that reduces the national RFS volume requirements.

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 national 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. On November 15, 2013, the EPA released its Notice of Proposed Rulemaking for the 2014 Renewable Fuel Standard. The EPA proposes setting the 2014 Renewable Volume Obligations, or RVO, for key categories of biofuel covered by the national RFS below the 2014 volumes set in 2007 by the Energy Independence and Security Act of 2007 and below the 2013 volumes. The proposal seeks comment on a range of total renewable fuel volumes for 2014, which includes a proposed total RVO of 15.2 billion gallons for total renewable fuel blended into transportation fuels of which corn ethanol would be approximately 13.0 billion gallons, down from the original legislative target of 18.15 billion gallons for total renewable fuels of which corn ethanol would have been approximately 14.4 billion gallons and 0.8 billion gallons less of corn ethanol than what was required in 2013. Our operations could be adversely impacted if the EPA accepts the proposed RVOs.

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 prices to increase 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 would 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, which peaked in 2007 and has declined steadily since then. 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.

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. In addition, a number of Kinergy’s suppliers may circumvent the marketing services we provide, causing our sales and profitability to decline.

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

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

In addition, some of our suppliers are potential competitors and, especially if the price of ethanol reaches historically high levels, they may seek to capture additional profits by circumventing our marketing services in favor of selling directly to our customers. If one or more of our major suppliers, or numerous smaller suppliers, circumvent our marketing services, our sales and profitability may decline.

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 covenants regarding its earnings before interest, taxes, depreciation and amortization (EBITDA) and fixed-charge coverage ratios. 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 high concentration of our sales within the ethanol marketing and production industry could result in a significant reduction in sales and negatively affect our profitability if demand for ethanol declines.

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

In addition to ethanol produced by the Pacific Ethanol Plants, we also depend on a small number of third-party suppliers for a significant portion of the ethanol we sell. If any of these suppliers does not continue to supply us with ethanol in adequate amounts, we may be unable to satisfy the demands of our customers and our sales, profitability and relationships with our customers will be adversely affected.

In addition to the ethanol produced by the Pacific Ethanol Plants, we also depend, and expect to continue to depend for the foreseeable future, on a small number of third-party suppliers for a significant portion of the total amount of ethanol that we sell. Our third-party suppliers are primarily located in the Midwestern United States. The delivery of ethanol from these suppliers is therefore subject to delays resulting from inclement weather and other conditions. If any of these suppliers is unable or declines for any reason to continue to supply us with ethanol in adequate amounts, we may be unable to replace that supplier and source other supplies of ethanol in a timely manner, or at all, to satisfy the demands of our customers. If this occurs, our sales, profitability and our relationships with our customers will be adversely affected.

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 the Pacific Ethanol 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 the Pacific Ethanol Plants. Present and future environmental laws and regulations, and interpretations of those laws and regulations, applicable to our operations, more vigorous enforcement policies and discovery of currently unknown conditions may require substantial expenditures that could have a material adverse effect on our results of operations and financial condition.

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

If we are unable to attract and retain key personnel, our ability to operate effectively may be impaired.

Our ability to operate our business and implement strategies depends, in part, on the efforts of our executive officers and other key employees. 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. Failure to attract or retain key personnel could have a material adverse effect on our business 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 2013 and 2012, three customers accounted for an aggregate of approximately 52% and 49% of our net sales, respectively. 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 amount of ethanol or dollar amount of sales 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.

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

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

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

We conduct most of our operations through subsidiaries and are dependent upon dividends or other intercompany transfers of funds from our subsidiaries to generate free cash flow. Moreover, some of our subsidiaries are limited in their ability to pay dividends or make distributions to us by the terms of their financing arrangements.

Risks Related to Ownership of our Common Stock

The conversion or exercise of our outstanding derivative securities or the issuance of shares of our common stock in lieu of accrued and unpaid dividends on our Series B Preferred Stock could substantially dilute your investment, reduce your voting power, and, if the resulting shares of common stock are resold into the market, or if a perception exists that a substantial number of shares may be issued and then resold into the market, the market price of our common stock and the value of your investment could decline significantly.

Our Series B Preferred Stock, which is convertible into our common stock, and outstanding options to acquire our common stock issued to employees, directors and others, and warrants to purchase our common stock, allow the holders of these derivative securities an opportunity to profit from a rise in the market price of our common stock. In addition, we may elect to issue shares of our common stock in lieu of accrued and unpaid cash dividends on our Series B Preferred Stock. We have issued common stock in respect of our derivative securities and accrued and unpaid dividends on our Series B Preferred Stock in the past and expect to do so in the future. If the prices at which our derivative securities are converted or exercised, or at which shares of common stock in lieu of accrued and unpaid dividends on our Series B Preferred Stock are issued, are lower than the price at which you made your investment, immediate dilution of the value of your investment will occur. Our issuance of shares of common stock under these circumstances will also reduce your voting power. In addition, sales of a substantial number of shares of common stock resulting from any of these issuances, or even the perception that these sales could occur, could adversely affect the market price of our common stock. As a result, you could experience a significant decline in the value of your investment as a result of both the actual and potential issuance of shares of our common stock.

We may incur significant non-cash expenses in future periods due to adjustments to the fair values of our outstanding warrants. These non-cash expenses may materially and adversely affect our reported net income or losses and cause our stock price to decline.

From 2010 through 2013, we issued in various financing transactions warrants to purchase shares of our common stock. The warrants were initially recorded at their fair values, which are adjusted quarterly, generally resulting in non-cash expenses or income if the market price of our common stock increases or decreases, respectively, during the period. For example, due to the substantial increase in the market price of our common stock in the first quarter of 2014 and because the exercise prices of these warrants were, as of March 31, 2014, well below the market price of our common stock, the fair values of the warrants and the related non-cash expenses were significantly higher in the first quarter of 2014 than in prior quarterly periods, which resulted in an unusually large non-cash expense for the quarter. These fair value adjustments will continue in future periods until all of our warrants are exercised or expire. We may incur additional significant non-cash expenses in future periods due to adjustments to the fair values of our outstanding warrants resulting from increases in the market price of our common stock during those periods. These non-cash expenses may materially and adversely affect our reported net income or losses and cause our stock price to decline.

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, including WDG and corn oil;

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 produce, sell and deliver ethanol on a cost-effective and timely basis;

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

losses resulting from adjustments to the fair values of our outstanding warrants to purchase our common stock;

changes in market valuations of companies similar to us;

stock market price and volume fluctuations generally;

regulatory developments or increased enforcement;

fluctuations in our quarterly or annual operating results;

additions or departures of key personnel;

our inability 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.

Furthermore, we believe that the economic conditions in California and other Western states, as well as the United States as a whole, could have a negative impact on our results of operations. Demand for ethanol could also be adversely affected by a slow-down in 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 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.

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

Unregistered Sales of Equity Securities

In April 2014, we issued an aggregate of 290,675 shares of common stock to one accredited investor upon the cashless exercise of outstanding warrants. The cashless exercise resulted in the cancellation of an aggregate of 492,750 shares of common stock otherwise issuable under the warrants. Exemption from the registration provisions of the Securities Act of 1933 for the transaction described above is claimed under Section 3(a)(9) of the Securities Act of 1933, among others.

Dividends

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

For each of the three months ended June 30, 2014 and 2013, we declared and paid in cash an aggregate of $0.3 million in dividends on our Series B Preferred Stock. We have never declared or paid cash dividends on our common stock and do not currently intend to pay cash dividends on our common stock in the foreseeable future. We currently anticipate that we will retain any earnings for use in the continued development of our business. The holders of our outstanding Series B Preferred Stock are entitled to dividends of 7% per annum, payable quarterly. Accumulated and unpaid dividends in respect of our Series B Preferred Stock must be paid prior to the payment of any dividends in respect of our common stock.

On May 23, 2014, we entered into an agreement with the holders of our Series B Preferred Stock under which we issued 0.1 million shares of our common stock in payment of $1.5 million of the $3.7 million of accrued and unpaid dividends at that time. In addition, the holders of our Series B Preferred Stock agreed to forbear from exercising any rights they may have with respect to the accrued and unpaid dividends until November 30, 2015, provided we remain current in the payment of future dividends.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES.

Not applicable.

ITEM 4. MINE SAFETY DISCLOSURES.

Not applicable.

ITEM 5. OTHER INFORMATION.

None.

ITEM 6. EXHIBITS.

Exhibit Number	Description

10.1	Second Amendment to Credit Agreement dated April 1, 2014, among Pacific Ethanol Holding Co. LLC, Pacific Ethanol Madera LLC, Pacific Ethanol Columbia, LLC, Pacific Ethanol Stockton LLC, Pacific Ethanol Magic Valley, LLC, PE Op Co., the Lenders signatory thereto, Wells Fargo Bank, N.A. and Amarillo National Bank (**) (1)
10.2	Third Amendment to Second Amended and Restated Credit Agreement dated April 1, 2014 among Pacific Ethanol Holding Co. LLC, Pacific Ethanol Madera LLC, Pacific Ethanol Columbia, LLC, Pacific Ethanol Stockton LLC, Pacific Ethanol Magic Valley, LLC, PE Op Co., the Lenders signatory thereto, Wells Fargo Bank, N.A., Amarillo National Bank and Pacific Ethanol, Inc. (**) (1)
10.3	First Amendment to Intercreditor Agreement and Consent dated April 1, 2014 by and among Pacific Ethanol Holding Co. LLC, Pacific Ethanol Madera LLC, Pacific Ethanol Columbia, LLC, Pacific Ethanol Stockton LLC, Pacific Ethanol Magic Valley, LLC and Wells Fargo Bank, N.A. (**) (1)
10.4	Underwriting Agreement, dated April 3, 2014, by and among Pacific Ethanol, Inc., Lazard Capital Markets LLC and Cowen and Company, LLC (**) (2)
10.5	Letter Agreement, dated May 23, 2014, by and among Pacific Ethanol, Inc. and the holders of Series B Cumulative Convertible Preferred Stock (**) (3)
10.6	Lender Assignment Agreement dated June 9, 2014 by and between CWD OC 522 Master Fund, Ltd. and Pacific Ethanol, Inc. (**) (4)
10.7	Lender Assignment Agreement dated June 9, 2014 by and between Candlewood Special Situations Master Fund, Ltd. and Pacific Ethanol, Inc. (**) (4)
10.8	Agreement for Purchase and Sale of Loans and Assignment of Commitment dated June 6, 2014 by and between Candlewood Credit Value Fund II, L.P. and Pacific Ethanol, Inc. (**) (4)
10.9	Pacific Ethanol, Inc. 2014 Short-Term Incentive Plan Description (**) (#) (5)
10.10	Kinergy Marketing LLC 2014 Short-Term Incentive Plan Description (**) (#) (5)
10.11	2006 Stock Incentive Plan (as amended through June 18, 2014) (#) (6)

Exhibit Number	Description

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

______________

(*)

Filed herewith.

(**)

Certain of the agreements filed as exhibits to this report 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.

(#)

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.

(1)

Filed as an exhibit to the Registrant’s current report on Form 8-K for April 1, 2014 filed with the Securities and Exchange Commission on April 2, 2014.

(2)

Filed as an exhibit to the Registrant’s current report on Form 8-K for April 3, 2014 filed with the Securities and Exchange Commission on April 3, 2014.

(3)

Filed as an exhibit to the Registrant’s current report on Form 8-K for May 23, 2014 filed with the Securities and Exchange Commission on May 28, 2014.

(4)

Filed as an exhibit to the Registrant’s current report on Form 8-K for June 6, 2014 filed with the Securities and Exchange Commission on June 10, 2014.

(5)

Filed as an exhibit to the Registrant’s current report on Form 8-K for June 13, 2014 filed with the Securities and Exchange Commission on June 13, 2014.

(6)

Filed as an exhibit to the Registrant’s registration statement on Form S-8 (333-196876) filed with the Securities and Exchange Commission on June 18, 2014.

SIGNATURES

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

	PACIFIC ETHANOL, INC.

Dated: August 14, 2014	By: /S/ BRYON T. MCGREGOR
	Bryon T. McGregor
	Chief Financial Officer
	(Principal Financial and Accounting Officer)

EXHIBITS FILED WITH THIS REPORT

Exhibit Number	Description

31.1	Certifications Required by Rule 13a-14(a) of the Securities Exchange Act of 1934, as amended, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2	Certifications Required by Rule 13a-14(a) of the Securities Exchange Act of 1934, as amended, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.1	Certification of Chief Executive Officer and Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
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