UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended ~~June~~September 30, 2025

☐ 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: 001-36475

Aemetis, Inc.

(Exact name of registrant as specified in its charter)

Delaware	26-1407544
(State or other jurisdiction	(I.R.S. Employer
of incorporation or organization)	Identification No.)

20400 Stevens Creek Blvd., Suite 700

Cupertino, CA 95014

(408) 213-0940

(Address and telephone number of principal executive offices)

Title of each class of registered securities	Trading Symbol	Name of each exchange on which registered
Common Stock, $0.001 par value	AMTX	NASDAQ

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

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☑ No ☐

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

Large accelerated filer ☐ Accelerated filer ☑ Non-accelerated filer ☐ Smaller reporting company ☑ Emerging growth company ☐

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

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

The number of shares outstanding of the registrant’s Common Stock on ~~July~~October 31, 2025, was 63 65,~~240~~568,~~956~~542 shares.

Table of Contents

AEMETIS, INC.

FORM 10-Q

Quarterly Period Ended ~~June~~September 30, 2025

INDEX

PART I--FINANCIAL INFORMATION


Item 1	Financial Statements.	4

Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations.	22

Item 3.	Quantitative and Qualitative Disclosures about Market Risk.	28

Item 4.	Controls and Procedures.	28

PART II--OTHER INFORMATION

Item 1.	Legal Proceedings.	29

Item 1A.	Risk Factors.	29

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds.	29

Item 3.	Defaults Upon Senior Securities.	29

Item 4.	Mine Safety Disclosures.	29

Item 5.	Other Information.	29

Item 6.	Exhibits.	29

Signatures		30

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SPECIAL NOTE REGARDING FORWARD-LOOKING STATEMENTS

We make forward-looking statements in this Quarterly Report on Form 10-Q, including statements regarding our assumptions, projections, expectations, targets, intentions, or beliefs about future events or other statements that are not historical facts. Forward-looking statements in this Quarterly Report on Form 10-Q include, without limitation, statements regarding management’s plans; trends in market conditions with respect to prices for inputs for our products and prices for our products; our ability to leverage approved feedstock pathways; our ability to leverage our location and infrastructure; our ability to incorporate lower-cost, non-food advanced biofuels feedstock at the Keyes Plant; our ability to expand into alternative markets for biodiesel and its byproducts, including continuing to expand our sales into international markets; our ability to maintain and expand strategic relationships with suppliers; our ability to access governmental carbon reduction incentives; our ability to supply gas into transportation markets; our ability to continue to develop, maintain, and protect new and existing intellectual property rights; our ability to adopt, develop and commercialize new technologies; our ability to extend or refinance our senior debt on terms reasonably acceptable to us or at all; our ability to continue to fund operations and our future sources of liquidity and capital resources; our ability to fund, develop, build, maintain and operate digesters, facilities and pipelines for our California Dairy Renewable Natural Gas segment; our ability to fund, develop and operate our carbon capture sequestration projects, including obtaining required permits; our ability to receive awarded grants by meeting all of the required conditions, including meeting the minimum contributions; our ability to obtain additional financing under the EB-5 program; our ability to generate and sell or utilize various credits, including California Low Carbon Fuel Standard ("LCFS"), federal Renewable Fuel Standard D3 RINs, production tax credits, and investment tax credits; our ability to improve margins; and our ability to raise additional debt and equity funding at the parent, subsidiary, or project level. Words or phrases such as “anticipates,” “may,” “will,” “should,” “could,” “believes,” “estimates,” “expects,” “intends,” “plans,” “predicts,” “projects,” “targets,” “will likely result,” “will continue” and similar expressions are intended to identify forward-looking statements. These forward-looking statements are based on current assumptions and predictions and are subject to numerous risks and uncertainties. Actual results or events could differ materially from those set forth or implied by such forward-looking statements and related assumptions due to certain factors, including, without limitation, the risks set forth under the caption “Risk Factors” below, which are incorporated herein by reference, as well as those business risks and factors described elsewhere in this report and in our other filings with the Securities and Exchange Commission (the “SEC”), including without limitation, our most recent Annual Report on Form 10-K and subsequent Form 10-Q filings. We undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise.

Table of Contents

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements

AEMETIS, INC.

CONSOLIDATED CONDENSED BALANCE SHEETS

(In thousands except for par value)

	June 30, 2025			December 31, 2024
	September 30, 2025			December 31, 2024
		Unaudited
Assets
Current assets:
Cash and cash equivalents	$	1,645		$	898
Cash and cash equivalents ($224 and $0 respectively from VIE)	$	5,584		$	898
Accounts receivable ($483 and $57 respectively from VIE)		2,699			1,805
Accounts receivable ($137 and $57 respectively from VIE)		1,649			1,805
Inventories ($236 and $157 respectively from VIE)		12,371			25,442
Inventories ($186 and $157 respectively from VIE)		4,777			25,442
Prepaid expenses ($57 and $85 respectively from VIE)		1,540			1,842
Prepaid expenses ($40 and $85 respectively from VIE)		1,633			1,842
Tax credit sale receivable ($0 and $8,125 respectively from VIE)		-			12,300
Other current assets ($2 and $2 respectively from VIE)		1,~~831~~911			2,409
Total current assets		2015,~~086~~554			44,696
Property, plant and equipment, net ($99,200 and $97,363 respectively from VIE)		204,641			199,392
Property, plant and equipment, net ($102,463 and $97,363 respectively from VIE)		209,965			199,392
Operating lease right-of-use ($1,090 and $648 respectively from VIE)		2,492			2,237
Operating lease right-of-use ($1,068 and $648 respectively from VIE)		2,370			2,237
Other assets ($6,140 and $6,057 respectively from VIE)		12,797			12,977
Other assets ($6,158 and $6,057 respectively from VIE)		13,230			12,977
Total assets	$	~~240~~241,~~016~~119		$	259,302
Liabilities and stockholders' deficit
Current liabilities:
Accounts payable ($6,834 and $5,917 respectively from VIE)	$	21,894		$	33,139
Accounts payable ($7,962 and $5,917 respectively from VIE)	$	29,903		$	33,139
Current portion of long term debt ($1,233 and $1,004 respectively from VIE)		247,615			63,745
Current portion of long-term debt ($1,266 and $1,004 respectively from VIE)		266,106			63,745
Short term borrowings ($90 and $290 respectively from VIE)		22,995			26,789
Short term borrowings ($0 and $290 respectively from VIE)		20,609			26,789
Other current liabilities ($492 and $1,920 respectively from VIE)		29,423			20,295
Other current liabilities ($338 and $1,920 respectively from VIE)		26,747			20,295
Total current liabilities		~~321~~343,~~927~~365			143,968
Long term liabilities:
Senior secured notes and revolving notes		-			169,826
EB-5 notes		1918,~~000~~500			21,500
Other long term debt ($47,771 and $47,803 respectively from VIE)		54,622			56,201
Other long-term debt ($48,261 and $47,803 respectively from VIE)		48,288			56,201
Series A preferred units ($128,880 and $126,593 respectively from VIE)		128,880			126,593
Series A preferred units ($131,010 and $126,593 respectively from VIE)		131,010			126,593
Other long term liabilities ($922 and $475 respectively from VIE)		4,842			5,142
Other long-term liabilities ($931 and $475 respectively from VIE)		4,808			5,142
Total long term liabilities		~~207~~202,~~344~~606			379,262
Stockholders' deficit:
Common stock, $0.001 par value; 80,000 authorized; 61,995 and 51,139 shares issued and outstanding each period, respectively		62			51
Common stock, $0.001 par value; 80,000 authorized; 65,000 and 51,139 shares issued and outstanding each period, respectively		65			51
Additional paid-in capital		~~327~~336,~~905~~814			305,329
Accumulated deficit		(~~610~~634,~~866~~613	)		(562,942	)
Accumulated other comprehensive loss		(67,~~356~~118	)		(6,366	)
Total stockholders' deficit		(~~289~~304,~~255~~852	)		(263,928	)
Total liabilities and stockholders' deficit	$	~~240~~241,~~016~~119		$	259,302

The accompanying notes are an integral part of the financial statements.

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AEMETIS, INC.

CONSOLIDATED CONDENSED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS)

(Unaudited, in thousands except for loss per share)

	For the three months ended June 30,						For the six months ended June 30,
	For the three months ended September 30,						For the nine months ended September 30,
	2025			2024			2025			2024
Revenues	$	5259,~~243~~190		$	6681,~~561~~441		$	95154,~~129~~319		$	~~139~~220,~~195~~636
Cost of goods sold		5559,~~598~~248			6877,~~367~~563			~~103~~162,~~564~~812			~~141~~219,~~613~~176
Gross loss		(3,355	)		(1,806	)		(8,435	)		(2,418	)
Gross profit (loss)		(58	)		3,878			(8,493	)		1,460
Selling, general and administrative expenses		78,~~319~~450			117,~~800~~750			1726,~~794~~244			2028,~~650~~400
Operating loss		(108,~~674~~508	)		(133,~~606~~872	)		(2634,~~229~~737	)		(2326,~~068~~940	)
Other expense (income):
Interest expense
Interest rate expense		11,~~235~~889			910,~~904~~096			2234,~~253~~142			1829,~~996~~092
Debt related fees and amortization expense		1,~~095~~061			1,~~820~~651			34,~~770~~831			34,~~241~~892
Accretion and other expenses of Series A preferred units		2,~~032~~034			3,~~477~~267			46,~~311~~345			610,~~788~~055
Other (income) expense		~~(1,112~~249	)		(181,225	)		(1,~~327~~078	)		49(1,176	)
Loss before income taxes		(23,~~924~~741	)		(2817,~~789~~661	)		(5578,~~236~~977	)		(5269,~~142~~803	)
Income tax (benefit) expense		~~(529~~6	)		~~385~~274			(7,~~312~~306	)		1,~~263~~537
Net loss	$	(23,~~395~~747	)	$	(2917,~~174~~935	)	$	(4771,~~924~~671	)	$	(5371,~~405~~340	)
Other comprehensive loss
Foreign currency translation loss		(3762	)		8(116	)		10(752	)		(36152	)
Comprehensive loss	$	(2324,~~398~~509	)	$	(2918,~~166~~051	)	$	(4772,~~914~~423	)	$	(5371,~~441~~492	)
Net loss per common share
Basic	$	(0.4137	)	$	(0.6638	)	$	(01.8724	)	$	(1.2460	)
Diluted		(0.4137	)	$	(0.6638	)	$	(01.8724	)	$	(1.2460	)
Weighted average shares outstanding
Basic		5763,~~676~~699			4447,~~417~~216			5558,~~144~~027			4344,~~153~~517
Diluted		5763,~~676~~699			4447,~~417~~216			5558,~~144~~027			4344,~~153~~517

The accompanying notes are an integral part of the financial statements.

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AEMETIS, INC.

CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited, in thousands)

	For the six months ended June 30,
	For the nine months ended September 30,
	2025			2024
Operating activities:
Net loss	$	(4771,~~924~~671	)	$	(5371,~~405~~340	)
Adjustments to reconcile net loss to net cash used in operating activities:
Share-based compensation		34,~~691~~976			46,~~946~~928
Stock issued for services		50150			-
Depreciation		47,~~708~~033			36,~~847~~121
Debt related fees and amortization expense		34,~~770~~831			34,~~241~~892
Intangibles and other amortization expense		2335			2436
Accretion and other expenses of Series A preferred units		46,~~311~~345			610,~~788~~055
Loss on asset disposals		-			3,644
Loss (gain) on asset disposals		(4	)		3,644
Gain on debt extinguishment		-			(162	)
Changes in operating assets and liabilities:
Accounts receivable		~~(444~~517	)		~~(145~~557	)
Inventories		1220,~~958~~336			8(1,~~028~~618	)
Prepaid expenses		~~274~~179			1,~~082~~566
Tax credit sale receivable		12,300			-
Other assets		~~150~~(676	)		(16,~~318~~930	)
Accounts payable		(9,~~467~~238	)		(53,~~961~~481	)
Accrued interest expense and fees		919,~~380~~484			1220,~~614~~873
Other liabilities		~~643~~2,894			1,~~243~~545
Net cash used in operating activities		(52,~~577~~509	)		(1520,~~372~~352	)
Investing activities:
Capital expenditures		(59,~~350~~441	)		(813,~~980~~470	)
Grant proceeds and other reimbursements received for capital expenditures		411			3,045
Net cash used in investing activities		(49,~~939~~030	)		(510,~~935~~425	)
Financing activities:
Proceeds from borrowings		2129,~~319~~246			812,~~436~~534
Repayments of borrowings		(2535,~~411~~729	)		(4,~~015~~841	)
Payments on Series A preferred financing		(2,200	)		-
Lender debt renewal and waiver fee payments		(495	)		(1,~~444~~445	)
Payments on finance leases		(~~162~~168	)		(~~161~~170	)
Proceeds from sales of common stock		1725,~~960~~487			1521,~~891~~680
Proceeds from exercise of stock options		257			36
Net cash provided by financing activities		1116,~~268~~398			1827,~~743~~794
Effect of exchange rate changes on cash, cash equivalents, and restricted cash		7(138	)		26(4	)
Net change in cash, cash equivalents, and restricted cash for period		~~759~~4,721			(2,~~538~~987	)
Cash, cash equivalents, and restricted cash at beginning of period		3,831			6,280
Cash, cash equivalents and restricted cash at end of period	$	48,~~590~~552		$	3,~~742~~293
Supplemental disclosures of cash flow information, cash paid:
Cash paid for interest	$	1112,~~404~~820		$	56,~~074~~272
Income taxes paid		-			878
Supplemental disclosures of cash flow information, non-cash transactions:
Settlement of AP via issuance of Common Stock		45			-
Settlement of Accounts Payable via issuance of Common Stock		45			-
Subordinated debt extension fees added to debt		680			~~340~~680
Fair value of warrants issued to subordinated debt holders		584			~~593~~916
Lender debt extension, waiver, and other fees added to debt		2,595			~~595~~695
Cumulative capital expenditures in accounts payable		14,429			11,360
Cumulative capital expenditures in accounts payable and accruals		17,228			10,060

The accompanying notes are an integral part of the financial statements.

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AEMETIS, INC.

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ DEFICIT

(Unaudited, in thousands)

For the six months ended June 30, 2025
For the nine months ended September 30, 2025
	Common Stock				Additional					Accumulated Other			Total
					Paid-in		Accumulated			Comprehensive			Stockholders'
Description	Shares		Dollars		Capital		Deficit			Loss			deficit
Balance at December 31, 2024		51,139	$	51	$	305,329	$	(562,942	)	$	(6,366	)		(263,928	)
Issuance of common stock		2,739		3		5,084		-			-			5,087
Stock options exercised		51		-		50		-			-			50
Stock-based compensation		-		-		2,308		-			-			2,308
Issuance and exercise of warrants		113		-		304		-			-			304
Foreign currency translation loss		-		-		-		-			13			13
Foreign currency translation gain		-		-		-		-			13			13
Net loss		-		-		-		(24,529	)		-			(24,529	)
Balance at March 31, 2025		54,042		54	$	313,075	$	(587,471	)	$	(6,353	)	$	(280,695	)
Issuance of common stock		7,664		8		12,960		-			-			12,968
Stock options exercised		289		-		207		-			-			207
Stock-based compensation		-		-		1,383		-			-			1,383
Issuance and exercise of warrants		-		-		280		-			-			280
Foreign currency translation loss		-		-		-		-			(3	)		(3	)
Net loss		-		-		-		(23,395	)		-			(23,395	)
Balance at June 30, 2025		61,995		62	$	327,905	$	(610,866	)	$	(6,356	)	$	(289,255	)
Issuance of common stock		2,892		3		7,624		-			-			7,627
Stock-based compensation		-		-		1,285		-			-			1,285
Issuance and exercise of warrants		113		-		-		-			-			-
Foreign currency translation loss		-		-		-		-			(762	)		(762	)
Net loss		-		-		-		(23,747	)		-			(23,747	)
Balance at September 30, 2025		65,000	$	65		336,814	$	(634,613	)	$	(7,118	)	$	(304,852	)

For the six months ended June 30, 2024
For the nine months ended September 30, 2024
	~~Common Stock~~	Common Stock					~~Additional~~	Additional						~~Accumulated Other~~	Accumulated Other			~~Total~~	Total
							~~Paid-in~~	Paid-in		~~Accumulated~~	Accumulated			~~Comprehensive~~	Comprehensive			~~Stockholders'~~	Stockholders'
Description	~~Shares~~	Shares		~~Dollars~~	Dollars		~~Capital~~	Capital		~~Deficit~~	Deficit			~~Loss~~	Loss			~~deficit~~	deficit
Balance at December 31, 2023		~~40,966~~	40,966	$	41$	41	$	~~264,058~~$	264,058	$	~~(475,405~~$	)(475,405	)	$	~~(5,671~~$	)(5,671	)	$	~~(216,977~~$	)(216,977	)
Issuance of common stock		~~1,523~~	1,523		2	2		~~5,511~~	5,511		-	-			-	-			~~5,513~~	5,513
Stock options exercised		14	14		-	-		36	36		-	-			-	-			36	36
Stock-based compensation		-	-		-	-		~~2,969~~	2,969		-	-			-	-			~~2,969~~	2,969
Issuance and exercise of warrants		~~113~~	113		-	-		~~593~~	593		-	-			-	-			~~593~~	593
Foreign currency translation gain		-			-			-			-				(44	)			(44	)
Foreign currency translation loss			-			-			-			-				(44	)			(44	)
Net loss		-	-		-	-		-	-		~~(24,231~~	)(24,231	)		-	-			~~(24,231~~	)(24,231	)
Balance at March 31, 2024		~~42,616~~	42,616	$	43$	43	$	~~273,167~~$	273,167	$	~~(499,636~~$	)(499,636	)	$	~~(5,715~~$	)(5,715	)	$	~~(232,141~~$	)(232,141	)
Issuance of common stock		~~3,166~~	3,166		3	3		~~10,375~~	10,375		-	-			-	-			~~10,378~~	10,378
Stock-based compensation		-	-		-	-		~~1,977~~	1,977		-	-			-	-			~~1,977~~	1,977
Foreign currency translation loss		-			-			-			-				8				8
Foreign currency translation gain			-			-			-			-				8				8
Net loss		-	-		-	-		-	-		~~(29,174~~	)(29,174	)		-	-			~~(29,174~~	)(29,174	)
Balance at June 30, 2024		~~45,782~~	45,782	$	46$	46	$	~~285,519~~$	285,519	$	~~(528,810~~$	)(528,810	)	$	~~(5,707~~$	)(5,707	)	$	~~(248,952~~$	)(248,952	)
Issuance of common stock			1,922			2			5,787			-				-				5,789
Stock-based compensation			-			-			1,982			-				-				1,982
Issuance and exercise of warrants			113			-			323			-				-				323
Foreign currency translation loss			-			-			-			-				(116	)			(116	)
Net income			-			-			-			(17,935	)			-				(17,935	)
Balance at September 30, 2024			47,817		$	48		$	293,611		$	(546,745	)		$	(5,823	)		$	(258,909	)

The accompanying notes are an integral part of the financial statements.

(Tabular data in thousands, except par value and per share data)

Table of Contents

1. General

Nature of Activities

Founded in 2006 and headquartered in Cupertino, California, Aemetis, Inc. (collectively with its subsidiaries on a consolidated basis referred to herein as “Aemetis,” the “Company,” “we,” “our” or “us”) is a renewable natural gas and biofuels company focused on the operation, acquisition, development, and commercialization of innovative technologies that lower fuel costs and reduce emissions. We do this by building a local circular bioeconomy using agricultural products and wastes. Our current operations include:

► California Ethanol – We own and operate a 65 million gallon per year capacity ethanol production facility in Keyes, California (the “Keyes Plant”). In addition to low carbon renewable fuel ethanol, the Keyes Plant produces Wet Distillers Grains (“WDG”), Distillers Corn Oil (“DCO”), and Condensed Distillers Solubles (“CDS”), all of which are sold as animal feed to local dairies and feedlots. The Keyes Plant also sells CO₂ ~~that~~captured ~~it captures~~ from ~~its~~the ~~fermenters for~~fermentation ~~use~~process to produce commercial grade CO₂ for the food, beverage, and other industries. We are implementing several energy efficiency initiatives at the Keyes Plant focused on reducing operating costs and lowering the carbon intensity of our ethanol to increase revenues.

► California Dairy Renewable Natural Gas – We produce Renewable Natural Gas (“"RNG”") in central California. We currently have ~~eleven~~twelve anaerobic digesters that produce biogas from dairy waste, a 36-mile biogas collection pipeline leading to a central RNG production facility, and an interconnection to inject the RNG into the utility natural gas pipeline for delivery for use as transportation fuel. We are actively expanding our RNG production, with several additional dairy digesters under construction, agreements with aover ~~total~~fifty ~~of 50~~ dairies, and a completed environmental review for an additional 24 miles of biogas pipeline. We are also building our own RNG fuel dispensing station, which is planned to begin operating in 2025.

► India Biodiesel – We own and operate a plant in Kakinada, India (“Kakinada Plant”) with a capacity to produce about 80 million gallons per year of high-quality distilled biodiesel from a variety of vegetable oil and animal waste feedstocks. ~~The~~Our ~~Kakinada~~plant ~~Plant~~ is one of the largest biodiesel production facilities in India. The Kakinada Plant also distills the crude glycerin byproduct from the biodiesel refining process into refined glycerin that is sold to the pharmaceutical, personal care, paint, adhesive, and other industries.

In addition, we are actively growing our business by seeking to develop or acquire new facilities, including the following key projects:

► Sustainable Aviation Fuel and Renewable Diesel – We are developing a sustainable aviation fuel (“SAF”) and renewable diesel (“RD”) production plant to be located at the Riverbank Industrial Complex in Riverbank, CA. The plant is currently designed to produce 90 million gallons per year of RD or 78 million gallons per year of SAF from renewable vegetable and animal oils obtained from our other biofuels plants and other North American sources. The plant is designed to use low-carbon hydroelectric electricity and renewable hydrogen that will be generated from byproducts of SAF/RD production. We received the Use Permit and California Environmental Quality Act (CEQA) approvals for the development of the plant in September 2023 and the Authority to Construct air permits in March 2024. We are continuing with the engineering and other required development activities for the facility.

► Carbon Capture and Underground Sequestration – We are developing a Carbon Capture and Underground Sequestration (“CCUS”) facility, also to be located at the Riverbank Industrial Complex, that is designed to inject carbon dioxide more than one mile underground for geologic storage to reduce greenhouse gas emissions to the atmosphere that contribute to global warming. We have completed the ~~first~~initial phase of drilling for the characterization well, and we are continuing engineering, permitting and other development activities for the characterization well and the permanent sequestration injection and monitoring wells.

Our current and planned businesses produce renewable fuels and reduce emissions, generating revenues from biofuel sales, federal Renewable Fuel Standard ("RFS") credits, federal Section 45Z production tax credits (“45Z PTC”), California Low Carbon Fuel Standard (“LCFS”) credits, and other investment and production tax credits.

Basis of Presentation and Consolidation

These consolidated financial statements include the accounts of Aemetis, Inc. and its subsidiaries. We consolidate all entities in which we have a controlling financial interest. A controlling financial interest is usually obtained through ownership of a majority of the voting interests. However, an enterprise must consolidate a variable interest entity (“VIE”) if the enterprise is the primary beneficiary of the VIE, even if the enterprise does not own a majority of the voting interests. The primary beneficiary is the party that has both the power to direct the activities of the VIE that most significantly impact the VIE’s economic performance, and the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE. We consider Aemetis Biogas LLC ("ABGL") to be a VIE because Aemetis, Inc. owns all of the outstanding common units of ABGL and is the primary beneficiary of ABGL's operations; accordingly, the assets, liabilities, and operations of ABGL and its subsidiaries are consolidated in these financial statements.

All intercompany balances and transactions have been eliminated in consolidation.

The accompanying consolidated condensed balance sheet as of ~~June~~September 30, 2025, the consolidated condensed statements of operations and comprehensive income (loss) for the three and ~~six~~nine months ended ~~June~~September 30, 2025 and 2024, the consolidated condensed statements of cash flows for the ~~six~~nine months ended ~~June~~September 30, 2025 and 2024, and the consolidated statements of stockholders’ deficit for the three and ~~six~~nine months ended ~~June~~September 30, 2025 and 2024, are unaudited. The consolidated condensed balance sheet as of December 31, 2024, is derived from the 2024 audited consolidated financial statements and notes thereto.

The financial statements in this report should be read in conjunction with the 2024 audited consolidated financial statements and notes thereto included in our annual report on Form 10-K for the year ended December 31, 2024. There have been no material changes to our significant accounting policies disclosed in Note 1 - Nature of Activities and Summary of Significant Accounting Policies and other Notes to the Consolidated Financial Statements included in our Annual Report on Form 10-K for the fiscal year ended December 31, 2024.

(Tabular data in thousands, except par value and per share data)

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The accompanying consolidated condensed financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“U.S. GAAP”) and pursuant to the rules and regulations of the U.S. Securities and Exchange Commission (“SEC”). Certain information and footnote disclosures normally included in financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to such rules and regulations. In the opinion of Company’s management, the unaudited interim consolidated condensed financial statements as of and for the three and ~~six~~nine months ended ~~June~~September 30, 2025 and 2024, have been prepared on the same basis as the audited consolidated statements as of and for the year ended December 31, 2024, and reflect all adjustments, consisting primarily of normal recurring adjustments, necessary for the fair presentation of its statement of financial position, results of operations and cash flows. The results of operations for the three and ~~six~~nine months ended ~~June~~September 30, 2025, are not necessarily indicative of the operating results for any subsequent quarter, for the full fiscal year, or any future periods.

Investment Tax Credits

We sell certain transferable Investment Tax Credits ("ITCs") that we generate from qualifying investments to third-party purchasers. We account for ITC sales in accordance with ASC 740 by electing the flow-through method. For the ~~six~~nine months ended ~~June~~September 30, 2025, the contractual net proceeds of ITC sales of $7.0 million are recorded as an income tax benefit. There were no ITC sales during the three months ended September 30, 2025.

2. Cash, Cash Equivalents, and Restricted Cash

The following table reconciles cash, cash equivalents, and restricted cash reported in the consolidated balance sheet to the total of the same amounts shown in the statement of cash flows.

	As of
	June 30, 2025		December 31, 2024
	September 30, 2025		December 31, 2024
Cash and cash equivalents	$	15,~~645~~584	$	898
Restricted cash included in other current assets		2		31
Restricted cash included in other assets		2,~~943~~966		2,902
Total cash, cash equivalents, and restricted cash shown in the statement of cash flows	$	48,~~590~~552	$	3,831

Restricted cash shown in the table above includes amounts set aside pursuant to the Aemetis Biogas 1 LLC Term Loan Agreement and the Aemetis Biogas 2 LLC Construction and Term Loan Agreement for financing reserves and construction contingencies.

3. Inventories

Inventories consist of the following:

	As of
	June 30, 2025		December 31, 2024
	September 30, 2025		December 31, 2024
Raw materials	$	82,~~072~~829	$	12,529
Work-in-progress		1,~~447~~598		1,683
Finished goods		~~2,852~~350		11,230
Total inventories	$	124,~~371~~777	$	25,442

As of ~~June~~September 30, 2025 , and December 31, 2024 , we recognized a lower of cost or net realizable value adjustment of $260 thousand and $112 thousand, respectively, related to inventory.

4. Property, Plant and Equipment

Property, plant and equipment consist of the following:

	As of
	June 30, 2025			December 31, 2024
	September 30, 2025			December 31, 2024
Land	$	8,~~643~~623		$	8,642
Plant and buildings		~~183~~200,~~783~~536			182,724
Furniture and fixtures		23,~~812~~030			2,686
Machinery and equipment		5,~~966~~908			5,721
Construction in progress		5445,~~738~~185			46,201
Property held for development		15,431			15,431
Finance lease right of use assets		2,889			2,889
Total gross property, plant & equipment		~~274~~281,~~262~~602			264,294
Less accumulated depreciation		(6971,~~621~~637	)		(64,902	)
Total net property, plant & equipment	$	~~204~~209,~~641~~965		$	199,392

For the three months ended ~~June~~September 30, 2025 and 2024, interest capitalized in property, plant and equipment was $1.1 million and $1.30 million, respectively. For the ~~six~~nine months ended ~~June~~September 30, 2025 and 2024, interest capitalized in property, plant and equipment was $23.12 million and $34.0 million, respectively.

(Tabular data in thousands, except par value and per share data)

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Construction in progress includes biogas dairy digesters, mechanical vapor recompression at the Keyes Plant, the Riverbank sustainable aviation fuel and renewable diesel plant, and CCUS facilities. Property held for development is the partially completed Goodland Plant. Depreciation begins for each project when construction is complete and the project is placed into service, and is calculated using the straight-line method to allocate the depreciable amount over the estimated useful life of the applicable asset as follows:

	Years
Plant and buildings		20 - 30
Machinery and equipment		5 - 15
Furniture and fixtures		3 - 5

For the three months ended ~~June~~September 30, 2025 and 2024, we recorded depreciation expense of $2.3 million and $2.03 million, respectively. For the nine ~~six~~ months ended ~~June~~September 30, 2025 and 2024, we recorded depreciation expense of $4.7.0 million and $36.81 million, respectively.

5. Debt

Debt consists of the following:

	June 30, 2025		December 31, 2024
	September 30, 2025		December 31, 2024
Third Eye Capital term notes	$	7,~~258~~274	$	7,212
Third Eye Capital revenue participation term notes		12,~~188~~216		12,110
Third Eye Capital revolving credit facility		3033,~~449~~246		31,434
Third Eye Capital revolving notes Series B		7681,~~257~~129		68,476
Third Eye Capital acquisition term notes		26,~~900~~961		26,788
Third Eye Capital Fuels Revolving Line		4447,~~936~~060		41,286
Third Eye Capital Carbon Revolving Line		2728,~~683~~727		26,302
Third Eye Capital short term promissory note		-		2,006
Biogas construction and term loans		48,~~436~~961		48,235
Cilion purchase obligation		7,~~351~~407		7,242
Subordinated notes		20,~~013~~609		19,391
EB-5 promissory notes		39,~~212~~297		41,615
Working capital loans		~~2,892~~-		5,102
Term loans on capital expenditures		~~657~~565		862
Total debt		344,232		338,061
Equipment financing		51		-
Less current portion of debt		270,610		90,534
Total debt		353,503		338,061
Total long term debt	$	73,622	$	247,527
Less current portion of debt		286,715		90,534
Total long term debt	$	66,788	$	247,527

Third Eye Capital Keyes Notes. On July 6, 2012, Aemetis, Inc., Aemetis Advanced Fuels Keyes, Inc. (“AAFK”), and Aemetis Facility Keyes, Inc. (“AFK”) entered into an Amended and Restated Note Purchase Agreement (the “Note Purchase Agreement”) with Third Eye Capital Corporation ("Third Eye Capital"). Pursuant to the Note Purchase Agreement, Third Eye Capital, as administrative agent on behalf of several noteholders, extended credit in the form of (i) senior secured term loans in an aggregate principal amount of approximately $7.2 million to replace existing notes held by Third Eye Capital (the “Term Notes”); (ii) senior secured revolving loans in an aggregate principal amount of $18.0 million (the “Revolving Credit Facility”); (iii) senior secured term loans in the principal amount of $10.0 million to convert the prior revenue participation agreement to notes (the “Revenue Participation Term Notes”); and (iv) senior secured term loans in an aggregate principal amount of $15.0 million (the “Acquisition Term Notes”) used to fund the cash portion of the acquisition of Cilion, Inc. On May 16, 2023, we entered into a new Revolving Notes Series B agreement with Third Eye Capital related to certain existing principal under the Revolving Credit Facility and for subsequent principal increases. The Term Notes, Revolving Credit Facility, Revolving Notes Series B, Revenue Participation Term Notes, and Acquisition Term Notes are referred to herein collectively as the "Third Eye Capital Keyes Notes." The Third Eye Capital Keyes Notes have been amended several times, and the current key terms are as follows:

A.	Term Notes. The Term Notes accrue interest at 14% per annum and mature on April 1, 2026. As of ~~June~~September 30, 2025, we had $7.3 million in principal, interest and fees outstanding under the Term Notes and $5236.52 thousand in unamortized debt issuance costs.
B.	Revolving Credit Facility. The Revolving Credit Facility accrues interest at prime rate plus 13.75% (21.2500% as of ~~June~~September 30, 2025) payable monthly in arrears and matures on April 1, 2026. As of ~~June~~September 30, 2025, we had $3033.85 million in principal, interest and waiver fees outstanding and $0.32 million in unamortized debt issuance costs under the Revolving Credit Facility.

C. Revolving Notes Series B. The Revolving Notes Series B accrue interest at prime rate plus 13.75% (21.2500% as of ~~June~~September 30, 2025) payable monthly in arrears and mature on April 1, 2026. As of ~~June~~September 30, 2025, we had $7781.06 million in principal, interest and waiver fees outstanding and $0.75 million in unamortized debt issuance costs under the Revolving Notes Series B.

D. Revenue Participation Term Notes. The Revenue Participation Term Notes accrue interest at 5% per annum and mature on April 1, 2026. As of ~~June~~September 30, 2025, we had $12.3 million in principal and interest outstanding under the Revenue Participation Term Notes and $8557.8 thousand in unamortized debt issuance costs.

E. Acquisition Term Notes. The Acquisition Term Notes accrue interest at prime rate plus 10.75% (18.2500% as of ~~June~~September 30, 2025) and mature on April 1, 2026. As of ~~June~~September 30, 2025, we had $27.1 million in principal, interest and redemption fees outstanding under the Acquisition Term Notes and $0.21 million in unamortized debt issuance costs. The outstanding principal balance includes a $7.5 million redemption fee which is not subject to interest.

(Tabular data in thousands, except par value and per share data)

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The Third Eye Capital Keyes Notes contain various covenants, including but not limited to, debt to plant value ratio, minimum production requirements, and restrictions on capital expenditures. The terms of the Notes allow the lender to accelerate the maturity in the event of a default that could reasonably be expected to have a material adverse effect on the Company, such as any change in the business, operations, or financial condition. We have evaluated the likelihood of such an acceleration event and determined such an event to not be probable in the next twelve months. The notes allow interest to be added to the outstanding principal balance. The notes are secured by first priority liens on all real and personal property of, assignment of proceeds from all government grants, and guarantees from our North American subsidiaries except for Aemetis Biogas LLC and its subsidiaries and contain cross-collateral and cross-default provisions. McAfee Capital, LLC (“McAfee Capital”), owned by Eric McAfee, the Company's Chairman and CEO, provided a guaranty of payment and performance secured by all Company shares owned by McAfee Capital and additional assets, and Mr. McAfee has also provided a personal guaranty of up to $10 million plus a pledge of his ownership interest in several personal assets.

Third Eye Capital Credit Facilities for Fuels and Carbon Revolving Lines. On March 2, 2022, Goodland Advanced Fuels, Inc. ("GAFI") and Aemetis Carbon Capture, Inc. (“ACCI”) entered into an Amended and Restated Credit Agreement (“Credit Agreement”) with Third Eye Capital, as administrative agent and collateral agent, and the lender parties thereto that provides two credit lines, one with GAFI (the “Fuels Revolving Line”) and a second with ACCI (the “Carbon Revolving Line”). Loans received under the Fuels Revolving Line had an original maturity date of March 1, 2025, and are now due on demand. They accrue interest per annum at a rate equal to the greater of (i) the prime rate plus 611.00% and (ii) ~~ten~~ fifteen percent (1015.0%). Loans received under the Carbon Revolving Line have a maturity date of March 1, 2026, and accrue interest per annum at a rate equal to the greater of (i) the prime rate plus 4.00% and (ii) eight percent (8.0%). The Credit Agreement ~~contain~~contains several affirmative and negative covenants, and loans under the Credit Agreement are secured by first priority liens on all real and personal property of and guarantees from the Company's North American subsidiaries except for Aemetis Biogas LLC. As of ~~June~~September 30, 2025 and December 31, 2024, GAFI had principal and interest outstanding of $4447.91 million and $41.7 million, respectively, classified as current debt. As of ~~June~~September 30, 2025, ACCI had principal and interest outstanding of $2829.32 million classified as current debt, and $0.74 million in unamortized debt issuance costs. As of December 31, 2024, ACCI had principal and interest outstanding of $2.5 million classified as current debt, $24.9 million classified as long-term debt, and $1.1 million in unamortized debt issuance costs.

Cilion Purchase Obligation. In connection with the merger between Aemetis Facility Keyes, Inc. and Cilion, Inc. (“Cilion”) on July 6, 2012, we incurred a $5.0 million payment obligation to Cilion shareholders as merger compensation. The liability accrues interest at 3% per annum. As of ~~June~~September 30, 2025, we had $7.4 million in principal and interest outstanding under the Cilion purchase obligation, classified as current debt. As of December 31, 2024, we had $7.2 million in principal and interest outstanding, classified as long-term debt.

Subordinated Notes. Between 2012 and 2013 , AAFK entered into Note and Warrant Purchase Agreements with two accredited investors pursuant to which it issued $3.4 million in notes to the investors (“Subordinated Notes”). The Subordinated Notes mature every six months, and the current maturity date is December 31, 2025. Upon maturity, the Subordinated Notes are renewable at our election for six-month periods with a fee of 10% of the original note amount added to the balance outstanding plus issuance of warrants exercisable for the purchase of 113 thousand shares of Aemetis, Inc. common stock at $0.01 per share with a two-year term. Interest accrues at 10% per annum and is due at maturity. Neither AAFK nor Aemetis may make any principal payments under the Subordinated Notes until all AAFK debts to Third Eye Capital are paid in full. As of ~~June~~September 30, 2025, and December 31, 2024, AAFK had, in aggregate, $20.69 million and $19.4 million in principal and interest outstanding, respectively, under the Subordinated Notes. As of ~~June~~September 30, 2025 and December 31, 2024, AAFK had $0.73 million and $0 in unamortized debt issuance costs related to the subordinated notes, respectively.

EB-5 Promissory Notes. EB-5 is a U.S. government program authorized by the Immigration and Nationality Act that is designed to foster employment-based visa preference for immigrant investors to encourage the flow of capital into the U.S. economy and to promote employment of U.S. workers. The Company's subsidiary AE Advanced Fuels, Inc. ("AEAF") entered into a Note Purchase Agreement dated March 4, 2011 (as further amended on January 19, 2012 and July 24, 2012) with Advanced BioEnergy, LP, a California limited partnership authorized by U.S. Citizenship and Immigration Services as a Regional Center to receive EB-5 investments, for the issuance of up to 72 subordinated convertible promissory notes (the “EB-5 Notes”) bearing interest at 2 to 3%. The EB-5 Notes are convertible into Aemetis, Inc. common stock at a conversion price of $30 per share. Advanced BioEnergy, LP received equity investments from foreign investors, and then Advanced BioEnergy, LP used the invested equity to make loans to AEAF. The EB-5 Notes are subordinated to the Company's senior secured debt to Third Eye Capital. On February 27, 2019, Advanced BioEnergy, LP, and AEAF entered into an Amendment to the EB-5 Notes that modified the stated maturity dates of the EB-5 Notes to provide automatic six-month extensions as long as the Advanced BioEnergy, LP investors’ immigration processes are in progress. Accordingly, notes derived from Advanced BioEnergy, LP equity provided by investors pending green card approval have been recognized as long-term debt while notes derived from Advanced BioEnergy, LP equity provided by investors who have obtained green card approval have been classified as current debt. As of ~~June~~September 30, 2025, and December 31, 2024, $34.8 million and $34.6 million was outstanding, respectively, on the EB-5 Notes.

In 2016, the Company launched its EB-5 Phase II funding (the "EB-5 Phase II Funding") and entered into certain Note Purchase Agreements with Advanced BioEnergy II, LP, a California limited partnership authorized to receive EB-5 equity funding investments. The Company's subsidiary Aemetis Advanced Products Keyes, Inc. received $4 million in loan funds from Advanced BioEnergy II, LP from 2018 to 2019. As of both ~~June~~September 30, 2025, and December 31, 2024, $4.45 million was outstanding on the notes under the EB-5 Phase II funding, respectively.

In July 2024, in connection with settlement of litigation initiated by a broker previously engaged by Advanced BioEnergy, LP, we entered into an agreement to pay the broker certain of its claimed fees. In April 2025, that broker initiated litigation against Aemetis, Inc. to collect $2.3 million (plus interest and fees) under the agreement. The liability previously accrued for the amount at issue in the litigation has been reclassified from debt as of December 31, 2024, to other current liabilities as of ~~June~~September 30, 2025.

(Tabular data in thousands, except par value and per share data)

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India Biodiesel Secured and Unsecured Loans. On November 13, 2023, the Company's subsidiary Universal Biofuels Private Limited ("UBPL") entered into a secured loan agreement with a trade partner in an amount not to exceed $3.6 million that is secured by the fixed and currents assets of the Kakinada Plant. On November 6, 2023, UBPL entered into a short-term loan agreement with a different trade partner in an amount not to exceed $1.27 million. Each loan bears interest at 18% that is payable monthly. The loans are repayable on demand by the lenders, or by the extended maturity date in November 2025. As of ~~June~~September 30, 2025, and December 31, 2024, UBPL had outstanding balances under these agreements totaling $20.90 million and $5.1 million, respectively.

~~Aemetis~~The ~~Biogas~~India 1biodiesel ~~LLC~~segment ~~Term~~maintains ~~Loan. On October 4, 2022, Aemetis Biogas 1 LLC ("AB1") entered into~~ a ~~Construction~~factoring ~~Loan~~arrangement ~~Agreement~~under ~~("AB1 Construction Loan") pursuant to~~ which ~~the~~we ~~lender~~leverage ~~made~~certain ~~available~~trade anreceivables ~~aggregate~~to ~~principal~~receive ~~amount~~short-term offunding ~~$25 million.~~from ~~Effective December 22, 2023, the AB1 Construction Loan was refinanced and replaced with~~ a ~~term~~third-party ~~loan~~financial ~~("AB1 Term Loan") that is secured by all personal and real property of AB1~~institution. ItWe ~~bears~~retain ~~interest~~the atrisk ~~a rate~~ of ~~9.25%~~nonpayment ~~per~~on ~~annum, to be adjusted every five years to equal~~ the ~~five-year~~transferred ~~Treasury Constant Maturity Rate~~receivables, asso ~~published by~~ the ~~Board~~arrangement ofdoes ~~Governors~~not ofmeet the ~~Federal~~criteria ~~Reserve~~for ~~System~~sale asaccounting ofunder ~~the~~ASC ~~adjustment date~~860, ~~plus~~and ~~5.00%~~we oraccount ~~(ii)~~for the ~~index~~funding ~~floor. Other~~as ~~material~~secured ~~terms~~borrowing. ofUnder ~~the~~this ~~loan include: (i) monthly payments of interest only beginning January 22~~arrangement, ~~2024,~~the ~~(ii)~~company ~~equal~~receives ~~monthly~~cash ~~payments~~advances ofwhich ~~principal~~are ~~and~~recorded ~~interest~~as ~~beginning January 22~~debt, ~~2025,~~ and ~~(iii)~~the afunds ~~maturity~~received ~~date~~are net of ~~December~~ ~~22,~~8.1% ~~2042,~~interest at which ~~time~~is ~~the~~recorded ~~entire~~as ~~unpaid principal amount, together with accrued and unpaid~~ interest, ~~is due and payable~~expense. ~~The~~We ~~AB1~~retain ~~Term~~our ~~Loan~~accounts ~~contains~~receivable ~~certain~~balances ~~financial~~in ~~covenants~~the tobalance besheet. ~~measured~~During ~~as of~~ the ~~last~~nine ~~day~~months ofended September ~~each~~30, ~~fiscal year beginning fiscal year end~~ 2025, ~~and~~ ~~annually~~we ~~for~~received ~~the~~a ~~term~~total of ~~the~~$23 ~~loan.~~million ~~The~~in ~~AB1~~draws ~~Term~~in ~~Loan~~this ~~also contains other affirmative and negative covenants~~agreement, ~~representations~~net ~~and warranties, and events~~ of ~~default~~8.1% ~~customary for loan agreements of this nature~~interest. As of both ~~June~~September 30, 2025, and December 31, 2024, ~~AB1~~ we had ~~$24.8 million and $25.1~~no ~~million~~ outstanding, ~~respectively,~~ debt under ~~the~~this ~~AB1 Term Loan~~agreement.

Aemetis Biogas 21 LLC ~~Construction and~~ Term Loan. On ~~July~~ October 284, ~~2023~~ 2022, Aemetis Biogas 21 LLC ("~~AB2~~AB1") entered into a Construction ~~and Term~~ Loan Agreement ("~~AB2~~AB1 Construction Loan"), pursuant to which the lender ~~has~~ made available an aggregate principal amount ~~not to~~ ~~exceed~~of $25 million. ~~The~~Effective December 22, 2023, the AB1 Construction Loan was refinanced and replaced with a term loan ("AB1 Term Loan") that is secured by all personal and real property of ~~AB2~~AB1. ~~The~~It ~~loan~~ bears interest at a rate of 89.7525% per annum, to be adjusted every five years ~~thereafter~~ to equal the five-year Treasury Constant Maturity Rate, as published by the Board of Governors of the Federal Reserve System as of the adjustment date, plus 5.00% or (ii) the index floor. Other material terms of the ~~AB2~~loan ~~Loan~~ include: (i) monthly payments of interest only beginning ~~August~~ January 1522, ~~2023~~2024, (ii) equal monthly payments of principal and interest beginning ~~August~~January 1522, 2025, and (iii) a maturity date of ~~July~~December 2822, ~~2043~~2042, at which time the entire unpaid principal amount, together with accrued and unpaid interest, is due and payable. The ~~AB2~~AB1 Term Loan contains certain financial covenants to be measured as of the last day of each fiscal year beginning fiscal year end 2025, and annually for the term of the loan. The ~~AB2~~AB1 Term Loan also contains other affirmative and negative covenants, representations and warranties, and events of default customary for loan agreements of this nature. As of ~~June~~September 30, 2025, and December 31, 2024, ~~AB2~~ AB1 had $24.46 million and $2325.91 million outstanding, respectively, ~~and unamortized discount issuance costs of~~ ~~$0.8 million and for both periods,~~ under the ~~AB2~~AB1 Term Loan.

~~Jessup~~Aemetis ~~land~~Biogas ~~acquisition~~2 ~~notes~~LLC Construction and Term Loan. InOn July ~~connection~~28, 2023, ~~with~~Aemetis ~~its~~Biogas ~~acquisition~~2 ofLLC ("AB2") entered into a Construction and Term Loan Agreement ("AB2 Loan"), pursuant to which the lender has made available an aggregate principal amount not to exceed $25 million. The loan is secured by all personal and real property of AB2. The loan bears interest at a ~~in November~~rate ~~2024~~of 8.75% per annum, to be adjusted every five years thereafter to equal the ~~Company's~~five-year ~~subsidiary~~Treasury ~~Aemetis~~Constant ~~RNG~~Maturity ~~Fuels~~Rate, 1as ~~LLC~~published by the Board of Governors of the Federal Reserve System as of the adjustment date, plus 5.00%. Other material terms of the AB2 Loan include: (~~"RNG1"~~i) ~~entered~~ ~~into~~monthly ~~two~~payments ~~installment~~of ~~note~~interest ~~agreements~~only ~~with~~beginning August ~~private~~15, ~~lenders~~2023, ~~totaling~~(ii) ~~$840~~equal ~~thousand~~monthly ~~with~~payments of principal and interest ~~payable~~beginning August ~~monthly~~15, 2025, and (iii) a maturity date of July 28, 2043, at 11which time the entire unpaid principal amount, together with accrued and unpaid interest, is due and payable.~~99%~~ The ~~per~~AB2 Loan contains certain financial covenants to be measured as of the last day of each fiscal year. beginning fiscal year end 2025, and annually for the term of the loan. The AB2 Loan also contains other affirmative and negative covenants, representations and warranties, and events of default customary for loan agreements of this nature. As of ~~June~~September 30, 2025, and December 31, 2024, ~~RNG1~~AB2 had $25.1 million and $23.9 million outstanding, ~~balances~~respectively, ~~under~~and ~~these~~unamortized ~~agreements~~discount ~~totaling~~issuance costs of $~~640~~0.8 ~~thousand~~ million and ~~$840~~for ~~thousand~~both periods, ~~respectively~~under the AB2 Loan.

Jessup land acquisition notes. In connection with its acquisition of real property in November 2024, the Company's subsidiary Aemetis RNG Fuels 1 LLC ("RNG1") entered into two installment note agreements with private lenders totaling $840 thousand with interest payable monthly at 11.99% per year. As of September 30, 2025, and December 31, 2024, RNG1 had outstanding balances under these agreements totaling $550 thousand and $840 thousand, respectively.

Maturity Date Schedule

The following table shows scheduled repayments for the Company's debt obligations by year:

Twelve Months ended June 30,	Debt Repayments
Twelve Months ended September 30,	Debt Repayments
2026	$	~~270~~286,~~610~~715
2027		2320,~~412~~010
2028		41,~~447~~524
2029		21,~~174~~405
2030		1,~~450~~535
Thereafter		4243,~~900~~076
Total debt		~~344~~354,~~993~~265
Debt issuance costs		(~~761~~762	)
Total debt, net of debt issuance costs	$	~~344~~353,~~232~~503

6. Basic and Diluted Net Income (Loss) Per Share

Basic net income (loss) per share is computed by dividing the income or loss attributable to common stockholders by the weighted average number of shares of common stock outstanding for the period. Diluted net income (loss) per share reflects the dilution of common stock equivalents such as options, convertible debt, and warrants to the extent the impact is dilutive. The following table shows the number of potentially dilutive shares excluded from the diluted net income (loss) per share calculation as of ~~June~~September 30, 2025 and 2024:

	As of
	June 30, 2025		June 30, 2024
	September 30, 2025		September 30, 2024
Common stock options and warrants		9,~~244~~139		7,~~731~~728
Debt with conversion feature at $30 per share of common stock		1,~~159~~161		1,~~277~~151
Total number of potentially dilutive shares		10,~~403~~300		98,~~008~~879

(Tabular data in thousands, except par value and per share data)

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7. Revenue and Accounts Receivable

California Ethanol Revenues: We sell our ethanol segment products to J.D. Heiskell, which sells them to third parties designated by us. We record revenue when we transfer ethanol into our storage tank, which is leased to J.D. Heiskell, and when product is loaded into shipping trucks for products other than ethanol. We also buy our corn feedstock from J.D. Heiskell. Transaction prices for ethanol sales and corn purchases are based on daily market prices. We invoice J.D. Heiskell each business day for the net balance between ethanol and other product sales and our corn purchases, and J.D. Heiskell pays on the next business day. The following table shows our sales in the California Ethanol segment:

For the three months ended June 30,

For the six months ended June 30,

For the three months ended September 30,

For the nine months ended September 30,

2025

2024

2025

2024

Ethanol sales

2731,~~724~~252

2933,~~437~~925

5587,~~783~~035

5488,~~823~~748

Wet distiller's grains sales

7,~~828~~305

98,~~302~~961

1523,~~828~~133

1827,~~516~~476

Other sales

12,~~736~~169

12,~~393~~048

35,~~425~~594

24,~~882~~931

Total

3740,~~288~~726

4044,~~132~~934

75115,~~036~~762

76121,~~221~~155

California Dairy Renewable Natural Gas Revenues: Our renewable natural gas ("RNG") production facilities as of ~~June~~September 30, 2025, include ~~eleven~~ twelve anaerobic digesters that process feedstock from dairies into biogas, a 36-mile collection pipeline leading to a central upgrading hub that produces RNG, and an interconnect to inject the RNG into the utility natural gas pipeline for delivery to customers for use as transportation fuel. We also generate sellable credits under the federal Renewable Fuel Standard (referred to as "D3 RINs") and the California Low Carbon Fuel Standard ("LCFS"), as well as other tax credit programs. We recognize revenue from natural gas sales when we inject the RNG into the utility pipeline and we recognize revenue from sales of D3 RINs and LCFS credits when we sell the credits. The following table shows sales in our RNG segment:

For the three months ended June 30,

For the six months ended June 30,

For the three months ended September 30,

For the nine months ended September 30,

2025

2024

2025

2024

Gas sales

~~292~~393

~~192~~238

~~551~~944

~~437~~676

LCFS credit sales

~~773~~1,187

~~324~~860

13,~~933~~120

12,~~512~~371

RIN sales

12,~~986~~416

13,~~082~~152

35,~~010~~426

36,~~441~~593

Total

3,~~051~~996

14,~~598~~250

59,~~494~~490

59,~~390~~640

India Biodiesel Revenues: We sell biodiesel to the government-owned India Oil Market Companies pursuant to tender offers, and we sell refined glycerin to private parties. We also occasionally sell feedstock based on market conditions. The following table shows sales in our India Biodiesel segment by product category:

For the three months ended June 30,

For the six months ended June 30,

For the three months ended September 30,

For the nine months ended September 30,

2025

2024

2025

2024

Biodiesel sales

913,~~541~~948

2331,~~708~~121

923,~~541~~489

5485,~~700~~821

Other sales

~~2,363~~520

1,~~123~~136

5,~~058~~578

24,~~884~~020

Total

1114,~~904~~468

2432,~~831~~257

1429,~~599~~067

5789,~~584~~841

Across all segments, revenue is recognized at the point in time when performance obligations have been met. Accounts receivable for all segments represent invoicing for products with varying payment terms, but with no variable consideration or financing. The opening balance of accounts receivable for all segments as of January 1, 2025 and 2024, was $1.8 million and $8.6 million, respectively, and the closing balance as of ~~June~~September 30, 2025, and December 31, 2024, were $$21.76 million and $1.8 million, respectively. Allowance for credit losses as of ~~June~~September 30, 2025, and December 31, 2024, for all segments was $0385 thousand and $36 thousand, respectively. There were no liabilities for unearned revenue for any segments as of ~~June~~September 30, 2025.

8. Leases

We are a party to operating leases for our corporate office in Cupertino, modular offices, and laboratory facilities. We have also entered into several finance leases for mobile equipment and for the Riverbank Industrial Complex. These finance leases have a purchase option at the end of the term that we are reasonably certain we will exercise, so the leases are classified as finance leases. All of our leases have remaining terms of one year to 13 years. We apply an accounting policy election to keep leases with an initial term of 12 months or less off the balance sheet, and recognize those lease payments in the Consolidated Statements of Operations as we incur the expenses.

We evaluate leases in accordance with ASC 842 – Lease Accounting. When discount rates implicit in leases cannot be readily determined, we use the applicable incremental borrowing rate at lease commencement to perform lease classification tests on lease components and to measure lease liabilities and right of use (ROU) assets. The incremental borrowing rate we use is based on weighted average baseline rates commensurate with our secured borrowing rate, over a similar term. At each reporting period when there is a new lease initiated, the rates established for that quarter are used.

(Tabular data in thousands, except par value and per share data)

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The components of lease expense are as follows:

	Three months ended June 30,				Six months ended June 30,
	Three months ended September 30,				Nine months ended September 30,
	2025		2024		2025		2024
Operating lease cost
Operating lease expense	$	~~202~~201	$	~~196~~195	$	~~392~~593	$	~~377~~571
Short term lease expense		4534		4232		86120		6395
Variable lease expense		23		3523		4669		6790
Total operating lease cost	$	~~270~~258	$	~~273~~250	$	~~524~~782	$	~~507~~756
Finance lease cost
Amortization of right-of-use assets	$	3020	$	30	$	6088	$	6090
Interest on lease liabilities		8993		8387		~~179~~272		~~169~~256
Total finance lease cost	$	~~119~~113	$	~~113~~117	$	~~239~~360	$	~~229~~346

Cash paid for amounts included in the measurement of lease liabilities:

Three months ended June 30,

Six months ended June 30,

Three months ended September 30,

Nine months ended September 30,

2025

2024

2025

2024

Operating cash flows used in operating leases

~~233~~191

~~246~~189

~~419~~609

~~414~~603

Operating cash flows used in finance leases

8993

8387

~~179~~272

~~169~~256

Financing cash flows used in finance leases

~~154~~6

~~154~~9

~~162~~168

~~161~~170

Supplemental non-cash flow information related to ROU asset and lease liabilities was as follows for the three and ~~six~~nine months ended ~~June~~September 30, 2025 and 2024:

	Three months ended June 30,						Six months ended June 30,
	Three months ended September 30,						Nine months ended September 30,
	2025			2024			2025		2024
Operating leases
Accretion of the lease liability	$	8480		$	8982		$	~~161~~241	$	~~164~~245
Amortization of right-of-use assets		~~118~~122			~~106~~112			~~231~~352		~~211~~325
The weighted average remaining lease term and weighted average discount rate as of June 30, 2025 are as follows:
The weighted average remaining lease term and weighted average discount rate as of September 30, 2025 are as follows:
Weighted Average Remaining Lease Term
Operating leases (in years)		11.02			68.52
Finance leases (in years)		11.75			12.64
Weighted Average Discount Rate
Operating leases		12.87	%		13.7	%
Finance leases		13.3	%		13.3	%

Supplemental balance sheet information related to leases is as follows:

	June 30, 2025			December 31, 2024
	September 30, 2025			December 31, 2024
Operating leases
Operating lease right-of-use assets	$	2,~~492~~370		$	2,237
Other current liability		~~551~~560			534
Other long term liabilities		21,~~019~~900			1,809
Total operating lease liabilities		2,~~570~~460			2,343
Finance leases
Property and equipment, at cost	$	2,889		$	2,889
Accumulated depreciation		(~~409~~437	)		(349	)
Property and equipment, net		2,~~480~~452			2,540
Other current liability		~~242~~244			244
Other long term liabilities		2,~~658~~743			2,639
Total finance lease liabilities		2,~~900~~987			2,883

(Tabular data in thousands, except par value and per share data)

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Maturities of operating and finance lease liabilities are as follows:

Twelve months ended June 30,	Operating leases			Finance leases
Twelve months ended September 30,	Operating leases			Finance leases
2026	$	~~837~~826		$	~~150~~145
2027		752			145
2028		~~706~~543			145
2029		108			145
2030		110			145
Thereafter		2,~~146~~130			9,815
Total lease payments		4,~~659~~469			10,~~545~~540
Less imputed interest		(2,~~089~~009	)		(7,~~645~~553	)
Total lease liability	$	2,~~570~~460		$	2,~~900~~987

We act as sublessor in certain leasing arrangements, primarily related to land and buildings. Fixed sublease payments received are recognized on a straight-line basis over the sublease term. Sublease income and head lease expense for these transactions are recognized on a net basis on the consolidated financial statements. Sublease income is recorded in the General and Administrative Expense section of the Consolidated Statements of Operations and Comprehensive Loss.

The components of lease income are as follows for the three and ~~six~~nine months ended ~~June~~September 30, 2025 and 2024, respectively:

	Three months ended June 30,				Six months ended June 30,
	Three months ended September 30,				Nine months ended September 30,
	2025		2024		2025		2024
Lease income	$	~~732~~754	$	~~516~~569	$	12,~~415~~170	$	1,~~007~~576

Future lease commitments to be received as of ~~June~~September 30, 2025, are as follows:

Twelve months ended June 30,
Twelve months ended September 30,
2026	$	1,~~742~~736
2027		1,~~758~~700
2028		1,~~547~~559
2029		1,~~594~~605
2030		~~1,012~~607
Thereafter		-
Total future lease commitments	$	7,~~653~~207

9. Stock Based Compensation

2019 Stock Plan

The Aemetis, Inc. Amended and Restated 2019 Stock Plan (the “2019 Stock Plan”) allows our Board of Directors or delegated Board committee to grant Incentive Stock Options, Non-Statutory Stock Options, Stock Appreciation Rights, Restricted Stock, Restricted Stock Units, Performance Units, Performance Shares, and other stock or cash awards to employees, directors, and consultants. During the ~~six~~nine months ended ~~June~~September 30, 2025, we issued stock options to employees exercisable for 1.8 million shares, issued 368 thousand shares of stock to members of our Board of Directors as compensation, and 29 thousand shares to an executive officer in lieu of cash compensation. The following table summarizes activity under the 2019 Stock Plan during the ~~six~~nine months ending ~~June~~September 30, 2025:

	Shares Available for Grant			Number of Shares Outstanding			Weighted-Average Exercise Price
Balance as of December 31, 2024		78			7,201		$	4.06
Authorized		2,148						-
Options Granted		(1,~~816~~832	)		1,~~816~~832			2.73
Common Stock Granted		(396	)		-			-
Exercised		-			(340	)		0.76
Forfeited/expired		7684			(7684	)		4.5437
Balance as of June 30, 2025		90			8,601		$	3.91
Balance as of September 30, 2025		82			8,609		$	3.91

The options outstanding as of ~~June~~September 30, 2025, include vested rights to purchase 5.6.0 million shares and the remaining purchase rights are not yet vested.

Inducement Equity Plan

In March 2016, the Board of Directors approved an Inducement Equity Plan authorizing the issuance of non-statutory options for the purchase of up 100,000 shares of common stock. This plan was not approved by stockholders, so it is available only for grants to prospective employees. As of ~~June~~September 30, 2025, there are no option grants outstanding under the Inducement Equity Plan.

(Tabular data in thousands, except par value and per share data)

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Stock-based Compensation Expense

Stock-based compensation is accounted for in accordance with ASC 718, Compensation - Stock Compensation, which requires the measurement and recognition of compensation expense for all stock-based awards made to employees, directors, and consultants based on estimated fair value on the grant date. We estimate the fair value using the Black-Scholes option pricing model and recognize that fair value as an expense over the vesting period of each grant using the straight-line method. We only record compensation cost for vested options. The Black-Scholes valuation model for stock-based compensation expense requires us to make assumptions and judgments about the variables used in the calculation, including the expected term (the period of time that the options granted are expected to be outstanding), the volatility of our common stock, a risk-free interest rate, expected dividends, and expected forfeitures. We use the simplified calculation of expected term described in SEC Staff Accounting Bulletin Topic 14, Share-Based Payment. Volatility is based on an average of the historical volatility of Aemetis, Inc. common stock during the period of time preceding the date of option issuance that matches the term of the option grant. The risk-free interest rate is based on the U.S. Treasury yield curve in effect at the time of grant for the treasury maturity term corresponding with the expected life of the option. We use an expected dividend yield of zero, as we do not anticipate paying any dividends in the foreseeable future. Expected forfeitures are assumed to be zero due to the small number of plan participants. To the extent actual forfeitures occur, the difference is recorded as an adjustment in the scheduled expense during the period of the forfeiture.

The weighted average fair value calculations for the options granted during the ~~six~~nine months ended ~~June~~September 30, 2025 and 2024, are based on the following assumptions:

	For the six months ended June 30,
	For the nine months ended September 30,
Description	2025			2024
Dividend-yield		-%	%		-%	%
Risk-free interest rate		4.~~30%~~29	%		43.~~08%~~93	%
Expected volatility		113.50%	%		115.42%	%
Expected life (years)		5.81			5.81
Market value per share on grant date	$	$ 2.73		$	$ 3.10
Fair value per option on grant date	$	$ 2.32		$	$ 2.65

During the ~~six~~nine months ended ~~June~~September 30, 2025 and 2024, we granted 396 thousand and 364 thousand shares of common stock under the 2019 Stock Plan, respectively, with a fair value on date of grant of $2.73 and $3.10, respectively, per share.

As of ~~June~~September 30, 2025, we had $64.07 million of total unrecognized compensation expense for option issuances, which we will amortize over the remaining vesting period for each applicable grant, which has a weighted average of 1.9991 years as of ~~June~~September 30, 2025.

(Tabular data in thousands, except par value and per share data)

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10. Warrants to Purchase Common Stock

On June 30, 2025, the maturity dates on two accredited investor's Subordinated Notes were extended to December 31, 2025. In connection with the extension, we issued the noteholders warrants exercisable for the purchase of 113 thousand shares of Aemetis, Inc. common stock with a term of two years and an exercise price of $0.01 per share. The warrants were ~~subsequently~~ fully exercised in July ~~the third quarter~~2025.

The following table summarizes warrant activity during the ~~six~~nine months ending ~~June~~September 30, 2025:

	Warrants Outstanding & Exercisable			Weighted - Average Exercise Price		Average Remaining Term in Years
Outstanding December 31, 2024		530		$	11.70		4.78
Granted		226			0.01
Exercised		(~~113~~226	)		0.01
Outstanding June 30, 2025		643		$	9.64		3.88
Outstanding September 30, 2025		530		$	11.70		4.03

All of the above outstanding warrants are fully vested and exercisable as of ~~June~~September 30, 2025.

The fair value calculations for issued warrants are based on the following weighted average factors:

	For the six months ended June 30,
	For the nine months ended September 30,
Description	2025			2024
Dividend-yield		-	%		-	%
Risk-free interest rate		3.99	%		4.2350	%
Expected volatility		90.48	%		~~101~~99.3685	%
Expected life (years)		2.00			2.00
Exercise price per share	$	0.01		$	0.01
Market value per share on grant date	$	2.59		$	54.2405
Fair value per share on grant date	$	2.58		$	54.2304

11. Aemetis Biogas LLC – Series A Preferred Financing

On December 20, 2018, Aemetis Biogas LLC ("ABGL") entered into a Series A Preferred Unit Purchase Agreement for the sale of Series A Preferred Units to Protair- X Americas, Inc., with Third Eye Capital acting as an agent. ABGL is authorized to issue 11,000,000 common units and 6,000,000 convertible, redeemable, secured, preferred membership units (the “Series A Preferred Units”). ABGL issued 6,000,000 common units to Aemetis, Inc. at a stated value of $5.00 per common unit, and 5,000,000 common units of ABGL are held in reserve as potential conversion units issuable to the Preferred Unit holder upon certain triggering events. From inception of the agreement through 2022, ABGL issued 6,000,000 Series A Preferred Units in exchange for $30.0 million in funding, reduced by a redemption of 20,000 Series A Preferred Units for $0.3 million. The original Preferred Unit Purchase Agreement included requirements for preference payments and mandatory redemption, grant of a security interest to the Preferred Unit holder in all assets of ABGL and its subsidiaries in connection with the preference payments due under the agreement, and several operating covenants.

The Preferred Unit Purchase Agreement has been amended multiple times. Most recently, in ~~May~~ October 2025, ABGL entered into an agreement entitled ~~Ninth~~Tenth Waiver and Amendment to Series A Preferred Unit Purchase Agreement ("PUPA ~~Ninth~~Tenth Amendment") with an effective date of ~~April~~August 3031, 2025, that, among other provisions, ~~requires~~extends the date by which ABGL is required to redeem all of the outstanding Series A Preferred Units byto ~~August~~December 31, 2025, ~~for~~and anchanges the aggregate redemption price ofto $~~116~~118.8 million , which includes a $2 million incremental fee for the PUPA ~~Ninth~~Tenth Amendment. The PUPA ~~Ninth~~Tenth Amendment further provides that if ABGL does not redeem the Series A Preferred Units by the redemption date, ABGL will enter into a credit agreement with Protair- X and Third Eye Capital effective as of ~~September~~January 1, ~~2025~~2026, and maturing ~~August~~January 311, ~~2026~~2027, in substantially the form attached to the PUPA ~~Ninth~~Tenth Amendment and specifies that entry into such credit agreement will satisfy the obligation to redeem the Series A Preferred Units. The credit agreement would bear an interest rate equal to the greater of (i) prime rate plus 10.0% and (ii) 16.0%. We evaluated ~~the PUPA Ninth Amendment and~~ prior similar amendments in accordance with ASC 470 and applied troubled debt restructuring accounting, resulting in no gain or loss from the execution of the particular amendment. In addition, consistent with ASC 470-60, we accreted the amount of principal and interest due using the effective interest method from the starting liability on the effective date of the amendment to the amount that would be due as of the maturity date of the credit agreement. Following this methodology, we recorded Series A Preferred Unit liabilities of $~~128~~131.90 million and $126.6 million as long-term liabilities as of ~~June~~September 30, 2025 , and December 31, 2024 , respectively.

12. Agreements

J.D. Heiskell Working Capital Agreements. Pursuant to a Corn Procurement and Working Capital Agreement with J.D. Heiskell, AAFK procures whole yellow corn from J.D. Heiskell. AAFK has the ability to obtain grain from other sources subject to certain conditions; however, in the past all AAFK grain purchases have been from J.D. Heiskell. Title to and risk of loss of the corn pass to AAFK when the corn is deposited into the Keyes Plant weigh bin. Pursuant to a separate agreement entered in May 2023, J.D. Heiskell also purchases all of our ethanol, WDG, corn oil, and CDS and sells them to marketing companies designated by us. We have designated Murex to purchase and market ethanol and A.L. Gilbert to purchase and market WDG and corn oil. Our relationships with J.D. Heiskell, Murex, and A.L. Gilbert are well established, and we believe that the relationships are beneficial to all parties involved in utilizing the distribution logistics, reaching a widespread customer base, managing inventory, and providing working capital relationships.

(Tabular data in thousands, except par value and per share data)

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The following table summarizes the J.D. Heiskell purchase and sales activity during the three and ~~six~~nine months ended ~~June~~September 30, 2025 and 2024:

For the three months ended June 30,

For the six months ended June 30,

For the three months ended September 30,

For the nine months ended September 30,

2025

2024

2025

2024

Ethanol sales

2731,~~724~~252

2932,~~437~~812

5587,~~783~~035

5487,~~823~~635

Wet distiller's grains sales

7,~~828~~305

98,~~302~~961

1523,~~828~~133

1827,~~516~~476

Corn oil sales

1,~~497~~949

1,~~161~~746

24,~~951~~900

24,~~452~~199

CDS sales

624

524

1539

2649

Corn purchases

29,~~935~~761

33,~~407~~170

6191,~~289~~050

6497,~~320~~489

	June 30, 2025		December 31, 2024
	September 30, 2025		December 31, 2024
Accounts receivable		71122		25

The agreements with J.D. Heiskell, Murex, and A.L. Gilbert include marketing and transportation services. For the three months ended ~~June~~September 30, 2025 and 2024, we expensed marketing costs of $0.6 million and $0.7 million, respectively, in connection with the marketing arrangements and these costs are included in Selling, General, and ~~Administration~~Administrative expenses. For the nine ~~six~~ months ended ~~June~~September 30, 2025 and 2024, we expensed marketing costs of $1.28 million inand $1.9 ~~both~~million, ~~periods~~respectively. For the three months ended ~~June~~September 30, 2025, we expensed transportation costs of $1.12 million related to sales of ethanol and $1.34 million related to sales of WDG. For the ~~six~~nine months ended ~~June~~September 30, 2025, we expensed transportation costs of $2.3.5 million related to sales of ethanol and $24.71 million related to sales of WDG. For the three months ended ~~June~~September 30, 2024, we expensed $01.81 million related to sales of ethanol and $1.5 million related to sales of WDG. For the ~~six~~Nine months ended ~~June~~September 30, 2024, we expensed transportation costs of $12.56 million related to sales of ethanol and $24.94 million related to sales of WDG. Transportation costs are included in costs of goods sold.

(Tabular data in thousands, except par value and per share data)

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Supply Trade Agreement. On July 1, 2022, UBPL entered into an operating agreement with Gemini Edibles and Fats India Private Limited (“Gemini”) pursuant to which Gemini supplies UBPL with feedstock up to a credit limit of $12.7 million and has a collateral interest in inventories, current assets, and fixed assets of UBPL. If UBPL fails to pay an invoice within the ten-day credit period, the outstanding balance bears interest at 18%. The agreement ~~continued~~is effective through ~~June~~July ~~2025~~2026. As of ~~June~~September 30, 2025, and December 31, 2024, UBPL had accounts payable of none and $6.2 million respectively, under this agreement.

Forward Sale Commitments. As of ~~June~~September 30, 2025, we have no forward sale commitments.

Natural Gas Purchase Agreement. As of ~~June~~September 30, 2025, we have a forward purchase agreement in place to buy approximately 3,700 MMBtu of natural gas per day at a fixed price of $3.30 per MMBtu through ~~October~~March ~~2025~~2026. We have elected to apply the normal purchases and normal sales scope exception under ASC 815, hence the natural gas purchased under this agreement is accounted for and included as cost of goods sold in our financial statements.

13. Segment Information

We recognize three reportable segments: “California Ethanol,” “California Dairy Renewable Natural Gas,” and “India Biodiesel.”

The “California Ethanol” segment includes our 65 million gallon per year ethanol plant in Keyes, California, and the adjacent land leased to upgrade our CO₂ production to commercial quality.

The “California Dairy Renewable Natural Gas” segment includes the production and sale of Renewable Natural Gas ("RNG") and associated environmental attributes, consisting of anaerobic digesters located at dairies, a 36-mile biogas collection pipeline, a biogas upgrading hub that produces RNG from the biogas, a pipeline interconnect, and ongoing construction of additional digesters.

The “India Biodiesel” segment includes our 80 million gallon per year biodiesel production plant in Kakinada, India, and administrative offices in Hyderabad, India.

We have additional operating segments that were determined not to be separately reportable segments, including our key projects under development which consist of a sustainable aviation fuel and renewable diesel production in Riverbank and Carbon Capture and Underground Sequestration ("CCUS") wells in California. Additionally, our corporate offices, Goodland Plant in Kansas, Riverbank Industrial Complex management, and our research and development facility in Minnesota are included in the “All Other” category. The corporate overhead expenses included in the "All Other" category total $5.0 million and $4.7 million for the three months ended September 30, 2025 and 2024, respectively; and $15.3 million and $15.7 million for the nine months ended September 30, 2025 and 2024, respectively.

The following tables summarize financial information by reportable segment for the three months ended ~~June~~September 30, 2025 and 2024:

	For the three months ended June 30, 2025
	For the three months ended September 30, 2025
	California Ethanol			California Dairy Renewable Natural Gas			India Biodiesel			All Other			Total
Revenues	$	3740,~~288~~726		$	3,~~051~~996		$	1114,~~904~~468		$	-		$	5259,~~243~~190
Gross profit (loss)		(31,~~806~~432	)		~~855~~1,300			~~(404~~74	)		-			(~~3,355~~58	)
Net Loss		(1211,~~611~~596	)		(3,~~533~~542	)		(~~586~~624	)		(67,~~665~~985	)		(23,~~395~~747	)
Interest expense including amortization of debt fees		8,~~001~~565			939			~~291~~25			3,~~099~~421			12,~~330~~950
Accretion and other expenses of Series A preferred units		-			2,~~032~~034			-			-			2,~~032~~034
Income tax expense		1-			-6			~~(530~~-	)		-			~~(529~~6	)
Depreciation		1,~~075~~024			1,~~012~~007			198			6597			2,~~350~~326
Stock-based compensation expense		-			-			-			1,433			1,433
Gain on asset disposal		-			-			(4	)		-			(4	)
Other amortization		11			-			-			-			11
Stock-based compensation expense		-			-			-			1,385			1,385
EBITDA		(3,523	)		450			(627	)		(2,068	)		(5,768	)
Other amortization		12			-			-			-			12
Capital expenditures		339			2,836			60			290			3,525
EBITDA		(1,995	)		444			(405	)		(3,082	)		(5,038	)
Capital expenditures		235			3,330			214			312			4,091

(Tabular data in thousands, except par value and per share data)

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	For the three months ended June 30, 2024
	For the three months ended September 30, 2024
	California Ethanol			California Dairy Renewable Natural Gas			India Biodiesel		All Other			Total
Revenues	$	4044,~~132~~934		$	14,~~598~~250		$	2432,~~831~~257	$	-		$	6681,~~561~~441
Gross profit (loss)		(3,921	)		(136	)		2,251		-			(1,806	)
Gross profit		85			1,897			1,896		-			3,878
Net Income (Loss)		(17,254	)		(5,349	)		1,210		(7,781	)		(29,174	)
Net income (loss)		(9,841	)		(7,617	)		1,397		(1,874	)		(17,935	)
Interest expense including amortization of debt fees		7,~~919~~911			~~730~~808			~~204~~30		2,~~871~~998			11,~~724~~747
Accretion and other expenses of Series A preferred units		-			3,~~477~~267			-		-			3,~~477~~267
Income tax expense		-			2-			~~383~~274		-			~~385~~274
Depreciation		1,~~043~~111			~~771~~866			~~180~~241		5556			2,~~049~~274
Stock-based compensation expense		-			-			-		1,~~977~~982			1,~~977~~982
Other amortization		12			-			-		-			12
Loss on asset disposals		3,644			-			-		-			3,644
Gain on debt extinguishment		(162	)		-			-		-			(162	)
EBITDA		(~~4,636~~969	)		(~~369~~2,676	)		1,~~977~~942		(23,~~878~~162	)		(51,~~906~~459	)
Capital expenditures		~~323~~154			43,~~306~~762			14257		~~754~~317			54,~~397~~490

	For the six months ended June 30, 2025
	For the nine months ended September 30, 2025
	California Ethanol			California Dairy Renewable Natural Gas			India Biodiesel			All other			Total
Revenues	$	75115,~~036~~762		$	59,~~494~~490		$	1429,~~599~~067		$	-		$	95154,~~129~~319
Gross profit (loss)		(810,~~744~~176	)		12,~~160~~460			(~~851~~777	)		-			(8,~~435~~493	)
		-			-			-			-			-
Net Income (Loss)		(27,521	)		(1,771	)		(2,298	)		(16,334	)		(47,924	)
Net loss		(39,117	)		(5,313	)		(2,922	)		(24,319	)		(71,671	)
Interest expense including amortization of debt fees		1625,~~462~~027			12,~~887~~826			~~747~~772			610,~~927~~348			2638,~~023~~973
Accretion and other expenses of Series A preferred units		-			46,~~311~~345			-			-			46,~~311~~345
Income tax expense (benefit)		1			(6,~~995~~989	)		(329	)		11			(7,~~312~~306	)
Depreciation		23,~~176~~200			23,~~021~~028			~~382~~579			~~129~~226			47,~~708~~033
Stock-based compensation expense		-			-			-			3,741			3,741
Gain on asset disposal		-			-			(4	)		-			(4	)
Other amortization		23			-			-			-			23
Stock-based compensation expense		-			-			-			5,126			5,126
EBITDA		(8,859	)		(547	)		(1,498	)		(5,526	)		(16,430	)
Other amortization		35			-			-			-			35
Capital expenditures		382			4,093			439			436			5,350
EBITDA		(10,854	)		(103	)		(1,904	)		(8,608	)		(21,469	)
Total assets as of June 30, 2025		53,230			124,099			25,462			37,225			240,016
Capital expenditures		617			7,423			653			748			9,441
Total assets as of September 30, 2025		54,703			129,932			20,821			35,663			241,119

	For the six months ended June 30, 2024
	For the nine months ended September 30, 2024
	California Ethanol			California Dairy Renewable Natural Gas			India Biodiesel		All other			Total
Revenues from external customers	$	76121,~~221~~155		$	59,~~390~~640		$	5789,~~584~~841	$	-		$	~~139~~220,~~195~~636
Gross profit (loss)		(9,~~579~~494	)		23,~~074~~971			56,~~087~~983		-			(21,~~418~~460	)
Net Loss		(31,354	)		(8,515	)		2,524		(16,060	)		(53,405	)
Net income (loss)		(41,195	)		(16,132	)		3,921		(17,934	)		(71,340	)
Interest expense including amortization of debt fees		1422,~~896~~807			12,~~366~~174			~~629~~659		58,~~346~~344			2233,~~237~~984
Accretion and other expenses of Series A preferred units		-			610,~~788~~055			-		-			610,~~788~~055
Income tax expense		-			36			1,~~227~~501		-			1,~~263~~537
Depreciation		23,~~009~~120			12,~~340~~206			~~388~~629		~~110~~166			36,~~847~~121
Stock-based compensation expense		-			-			-		46,~~946~~928			46,~~946~~928
Other amortization		2436			-			-		-			2436
Gain on debt extinguishment		(162	)		-			-		-			(162	)
Loss on asset disposals		3,644			-			-		-			3,644
EBITDA		(1011,~~781~~750	)		(1,~~015~~661	)		46,~~768~~710		(52,~~658~~496	)		(109,~~656~~197	)
Capital expenditures		~~430~~584			710,~~149~~911			~~318~~575		1,~~083~~400			813,~~980~~470
Total assets as of December 31, 2024		57,076			126,113			37,587		38,526			259,302

California Ethanol: Sales of ethanol, WDG, and corn oil to one customer (J.D. Heiskell) accounted for 99.45% and 9597.60% of our California Ethanol segment revenues for the three months ended ~~June~~September 30, 2025 and 2024, respectively. Sales to J.D. Heiskell account for 99.4% and 9298.96% of our California Ethanol segment revenues for the ~~six~~nine months ended ~~June~~September 30, 2025 and 2024. J.D. Heiskell accounts for over 90% of all Ethanol Segment sales for the three and ~~six~~nine months ended ~~June~~September 30, 2025 and 2024.

California Dairy Renewable Natural Gas: Sales of RNG during the three and ~~six~~ nine months ended ~~June~~September 30, 2025 and 2024, were to a single customer. We sold D3 RINs and LCFS credits to two other customers.

India Biodiesel: For the three months ended ~~June~~September 30, 2025 , ~~four~~ three customers accounted for 3442%, 2528%, ~~23%,~~ and ~~16%~~ 26% of our India Biodiesel segment's revenues. For the three months ended ~~June~~September 30, 2024, three biodiesel customers accounted for 4440%, 3429%, and 17 28% of the segment's revenues. For the ~~six~~nine months ended ~~June~~September 30, 2025, four customers accounted for 2835%, 2623%, 2023%, and 1914% of the segment's revenues. For the ~~six~~nine months ended ~~June~~September 30, 2024, three customers accounted for 4241%, 3633%, and 1721% of the segment's revenues.

14. Related Party Transactions

The Company owes Eric McAfee, our Chairman and CEO, and McAfee Capital LLC (“McAfee Capital”), which is owned by Mr. McAfee, $1.3 million as of ~~June~~September 30, 2025, in connection with employment agreements, bonus awards, expense reimbursements, and guarantee fees in connection with guarantees of the Company's indebtedness to Third Eye Capital provided by McAfee Capital and by Mr. McAfee personally.

(Tabular data in thousands, except par value and per share data)

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15. Subsequent Events

WeOn October ~~evaluated~~15, ~~subsequent~~2025, ~~events~~Aemetis ~~through~~Biogas ~~the~~LLC ~~date~~("ABGL") entered ~~these~~into ~~financial~~an ~~statements~~agreement ~~were~~entitled ~~issued,~~Tenth Waiver and weAmendment ~~concluded~~to Series A Preferred Unit Purchase Agreement ("PUPA Tenth Amendment") with an effective date of August 31, 2025, that ~~there~~provides, ~~were~~among noother ~~material~~provisions, ~~subsequent~~the ~~events~~requirement ~~requiring~~for ~~disclosure~~ABGL to redeem all outstanding Series A Preferred Units by December 31, 2025, for an aggregate redemption price of $118.8 million or to enter into a credit agreement in the form attached to the PUPA Tenth Amendment. The PUPA Tenth Amendment is described further in Note 11 Aemetis Biogas LLC - Series A Preferred Financing.

16. Liquidity and Going Concern

The accompanying financial statements have been prepared contemplating the realization of assets and satisfaction of liabilities in the normal course of business. This approach to presentation is qualified by the following additional descriptions of our financial position.

Debt

We have a substantial amount of accumulated debt, and our senior lender has a security interest in substantially all of the Company's assets. We have been reliant on our senior secured lender to provide extensions to the maturity dates of its debt facilities and have been required to remit substantially all excess cash from tax credit sales as payments of that debt, in addition to other periodic payments. In order to meet our obligations during the next twelve months, we will need to refinance debt with our senior lender for amounts becoming due in the next twelve months or receive its continued cooperation.

Operational Cash Flows

We do not currently generate positive cash flow from our consolidated operations. We are pursuing the following strategies to improve liquidity:

California Ethanol

Optimize Operations. We plan to continue to operate the Keyes Plant and to optimize operating parameters based on market conditions. For example, we recently improved ethanol yields and operating margins by scaling back throughput by about 15%.

Reduce Natural Gas Use and Reduce Ethanol Carbon Intensity. We are constructing a Mechanical Vapor Recompression ("MVR") system that will reduce the Keyes Plant's natural gas consumption by about 80% and lower the carbon intensity of the ethanol produced at the Plant. This will reduce overall fuel costs and volatility and will increase income from LCFS credits and Section 45Z tax credits. The MVR project is expected to become operational in the first half of 2026.

Monetize New Section 45Z Tax Credits. The Keyes Plant started earning Section 45Z tax credits effective January 1, 2025, and we are in the process of monetizing the credits that have been earned so far. The recent federal tax and budget legislation referred to as the "One Big Beautiful Bill" that was enacted in July 2025 contains provisions that are expected to increase our future income from Section 45Z tax credits for ethanol production, including an increase in the credit amount earned for each gallon of ethanol we produce and an extension of the term of the credits to a total of five years.

Evaluate New Technologies. We continue to evaluate other opportunities to improve the Keyes Plant's financial performance by adopting new technologies or process changes that ~~allow for~~ further ~~improvement to~~improve energy efficiency, ~~use~~decrease offeedstock ~~lower~~costs, ~~cost~~increase ~~feedstocks,~~co-product yields, and create other margin enhancements.

California Renewable Natural Gas

Operate ~~Eleven~~ Twelve Digesters. We completed construction of four new digesters in 2024 soand ~~will~~one ~~generate~~new ~~full~~digester ~~cash~~in ~~flow~~2025. ~~from~~We now ~~continuing~~have totwelve ~~operate~~operating ~~our~~digesters ~~eleven~~that ~~existing~~receive ~~digesters~~feedstock ~~for~~from afifteen ~~full~~dairies ~~year~~and ~~in 2025~~receive tothe ~~produce~~correspondingly ~~and~~higher ~~sell~~cash ~~Renewable~~flows ~~Natural~~from ~~Gas~~the ~~and~~increased ~~the~~number ~~associated~~of ~~environmental~~operating ~~attributes~~facilities.

Construct New Digesters. We plan to continue to build new dairy digesters that increase cash flow as allowed by capital availability. We have agreements with ~~a total of~~ over fifty dairies and expect the next set of digesters to begin producing biogas in the ~~third~~second quarter of ~~2025~~2026. We are seeking debt from a variety of sources to facilitate additional digester construction.

Increase LCFS Credit Revenue. In the second quarter of 2025, the California Air Resource Board ("CARB") approved provisional pathways for seven dairy locations, which is expected to increase our LCFS credit revenue from biogas we produce from those dairies by about ~~100~~160% starting in the ~~third~~fourth quarter of 2025, compared to the temporary pathways that previously applied. We still generate LCFS credits under temporary pathways at ~~four~~five operating digesters and expect LCFS revenue to increase further as we obtain more provisional LCFS pathways for those dairies. In addition, CARB's recently approved amendments to the LCFS regulation became effective July 1, 2025, which are expected to reduce the oversupply of LCFS credits and lead to higher credit prices in the future.

Monetize New Section 45Z Tax Credits. Our RNG production started earning Section 45Z production tax credits effective January 1, 2025, and we are in the process of monetizing the credits earned so far. The recent federal tax and budget legislation referred to as the "One Big Beautiful Bill" that was enacted in July 2025 contains provisions that are expected to increase our future income from Section 45Z tax credits for RNG production, including an increase in the credit amount earned for each MMBtu of RNG we produce and an extension of the term of the credits to a total of five years.

India Biodiesel

Continue Sales to OMCs. We plan to continue to operate the Kakinada Plant to produce biodiesel and glycerin and to sell the biodiesel to government-owned Oil Marketing Companies ("OMCs") to help them achieve government mandates to increase the percentage of biodiesel used in India as a percentage of total diesel uses.

Expand Operations and Plan for IPO. We have hired a new executive team in India to help develop plans for additional growth of our India business and to execute on a potential public stock offering of our India subsidiary.

Maintain Self-Sustaining Cash Flow. Notably, our India business has been self-sustaining from a cash and liquidity perspective for several years, and we expect this to continue.

Financing

While we are implementing our plans to improve liquidity, we have been raising cash for operations by selling equity through our at-the-market stock registration, and we expect to continue to do so. We also plan to seek additional funding for existing and new business opportunities through a combination of working with our senior lender, restructuring or refinancing existing loan agreements, entering into additional debt agreements for specific projects, ~~and~~ obtaining project specific equity and debt for development projects, and obtaining additional debt from the current EB-5 Phase II offering.

Summary

As discussed above, there have been several events in the last ~~six~~nine months that are expected to improve our ability to execute on the strategies for improving liquidity, including, for example, recent approval of biogas LCFS pathways, effectiveness of the new LCFS rule amendments, availability of Section 45Z tax credits for both ethanol and RNG production, and hiring of a new CFO in India to help manage an expected IPO.

Notwithstanding our plans to improve liquidity and these favorable recent events, the extent of our debt and reliance on our senior secured lender, along with expected near-term shortfalls in cash flow from operations, require us to ~~continue~~state ~~to carry forward the conclusion~~ that there is substantial doubt about our ability to continue as a going concern over the next twelve months.

(Tabular data in thousands, except par value and per share data)

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Our Management’s Discussion and Analysis of Financial Condition and Results of Operations (MD&A) is provided in addition to the accompanying consolidated condensed financial statements and notes to assist readers in understanding our results of operations, financial condition, and cash flows. MD&A is organized as follows:

● Overview. Discussion of our business and overall analysis of financial and other highlights affecting us, to provide context for the remainder of MD&A.

● Results of Operations. An analysis of our financial results comparing the three and ~~six~~nine months ended ~~June~~September 30, 2025 and 2024.

●

Liquidity and Capital Resources. An analysis of changes in our balance sheets and cash flows and discussion of our financial condition.

●

Critical Accounting Policies and Estimates. Accounting policies and estimates that we believe are important to understanding the assumptions and judgments incorporated in our reported financial results and forecasts.

The following discussion should be read in conjunction with our consolidated condensed financial statements and accompanying notes included in Item 1 of Part 1 of this report. The following discussion contains forward-looking statements that reflect our plans, estimates and beliefs. Our actual results could differ materially from those discussed in the forward-looking statements. Factors that could cause or contribute to these differences include those discussed below and elsewhere in this Report and in other reports we file with the SEC. All references to years relate to the calendar year ended December 31 of the particular year.

Overview

Founded in 2006 and headquartered in Cupertino, California, we are ana ~~international~~ renewable natural gas and biofuels company focused on the operation, acquisition, development, and commercialization of innovative ~~low~~technologies ~~and~~that ~~negative~~lower ~~carbon~~fuel ~~intensity~~costs ~~products~~ and ~~technologies~~reduce emissions. We operate in three reportable segments consisting of “California Ethanol,” “California Dairy Renewable Natural Gas,” and “India Biodiesel.” We have other operating segments determined not to be separately reportable that are collectively represented by the “All Other” category. Our mission is to ~~generate~~produce innovative renewable fuel solutions that benefit communities and improve the environment. We are executing our mission by building a circular bioeconomy using agricultural products and waste to produce low carbon renewable fuels that create jobs, reduce greenhouse gas (“GHG”) emissions, and improve air quality. For revenue and other information regarding our operating segments, see Note 13 - Segment Information, of the Notes to Consolidated Financial Statements of this Form 10-Q.

Our California Ethanol segment consists of a 65 million gallon per year capacity ethanol production facility located in Keyes, California (the “Keyes Plant”) that we own and operate. In addition to low carbon renewable fuel ethanol, the Keyes Plant produces alcohol for other uses, Wet Distillers Grains (“WDG”), Distillers Corn Oil (“DCO”), and Condensed Distillers Solubles (“CDS”). WDG, DCO, and CDS are sold as animal feed to more than 80 local dairies and feedlots. We also capture the Carbon Dioxide (“CO2”) generated by our fermenters and sell it to an industrial gas company tothat ~~produce~~liquifies ~~liquid~~the CO₂ ~~that~~to ~~it sells~~ sell to food, beverage, and industrial customers. We are implementing several energy efficiency initiatives focused on lowering the carbon intensity ("CI") of our ethanol, primarily by decreasing the use of fossil natural gas. Recently completed energy efficiency projects include high efficiency heat exchangers and a solar micro grid. A significant energy efficiency project in progress is the Mechanical Vapor Recompression (MVR) system that will use low carbon electricity instead of natural gas. These changes will reduce our energy costs ~~and will also~~ , lower the ~~carbon intensity (~~CI) of the ethanol we produce, and generate increased cash flows from LCFS and tax credits. We have already begun procuring MVR equipment and expect itthe system to be ~~installed~~operational ~~later this year and begin operating~~ in the first half of 2026.

Our California Dairy Renewable Natural Gas segment operates anaerobic digesters at local dairies near the Keyes Plant (many of whom also purchase WDG produced by the Keyes Plant as animal feed) to produce biogas from dairy waste, transports the biogas by pipeline to the Keyes Plant site, and converts the biogas to Renewable Natural Gas (“RNG”) that is delivered to customers through the utility natural gas pipeline. We currently have ~~eleven~~twelve operating digesters that receive waste from ~~twelve~~ fifteen dairies, and we are actively growing with additional digesters under construction. We have constructed 36 miles of biogas collection pipeline and have received environmental approval to construct an additional 24 miles of pipeline. We currently have agreements to build digesters and receive waste from ~~a total of~~ over 50 dairies and are seeking to sign agreements with additional dairies.

Our India Biodiesel segment includes a biodiesel production plant in Kakinada, India (“Kakinada Plant”) with a production capacity of about 80 million gallons per year. The plant produces high quality distilled biodiesel and refined glycerin for customers in India. We believe the Kakinada Plant is one of the highest capacity biodiesel production facilities in India. The Kakinada Plant is capable of processing a variety of vegetable and animal oil waste feedstocks into biodiesel that meets applicable product standards. Our Kakinada Plant also distills the crude glycerin coproduct from the biodiesel refining process into refined glycerin, which is sold to the pharmaceutical, personal care, paint, adhesive, and other industries.

Our "All Other" segment consists of our projects that are under development, including our planned Carbon Capture and Underground Sequestration ("CCUS") operations and the planned sustainable aviation fuel ("SAF") and renewable diesel ("RD") plant in Riverbank, California. The All Other segment also includes our research and development facility in Minneapolis, Minnesota, operation of the Riverbank Industrial Complex, and our corporate offices in Cupertino, California.

Our SAF/RD production plant is currently designed to produce 90 million gallons per year of combined SAF/RD or 78 million gallons per year of SAF from feedstocks consisting of renewable waste vegetable and animal oils. Our project is located at the Riverbank Industrial Complex in Riverbank, California. We signed a lease with an option to purchase the Riverbank Industrial Complex in 2021 and took possession of the site in 2022. In 2023, we received a Use Permit and the California Environmental Quality Act ("CEQA") approval for the SAF/RD plant, and in 2024 we received Authority to Construct air permits for the plant. We are continuing with development activities, including engineering, and financing. The Riverbank site has access to low carbon hydroelectric power, and our plant is designed to use renewable hydrogen that will be produced from byproducts of the SAF/RD production process.

Our planned CCUS projects will compress and inject CO₂ into deep wells that are monitored to ensure the long-term sequestration of carbon underground. California’s Central Valley has been identified as one of the world’s most favorable regions for large-scale CO₂ injection projects due to the subsurface geologic formations that absorb and contain CO₂ gas. The two initial Aemetis CCUS injection projects are being designed to capture and sequester more than two million metric tons per year of CO₂ at the Aemetis biofuels plant sites in Keyes and Riverbank, California. Once operational, these projects will generate revenue by selling California LCFS credits and federal Internal Revenue Code Section 45Q tax credits.

(Tabular data in thousands, except par value and per share data)

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Our Minneapolis, Minnesota research and development laboratory evaluates and develops technologies that would use low carbon intensity and waste feedstocks to produce low or below zero carbon intensity biofuels and biochemicals. We are focused on processes that extract sugar from cellulosic feedstocks and produce low carbon ethanol, renewable hydrogen, SAF, and RD.

Results of Operations

Three Months Ended ~~June~~September 30, 2025, Compared to Three Months Ended ~~June~~September 30, 2024

Revenues

Our revenues are derived primarily from sales of ethanol and WDG for our California Ethanol segment, renewable natural gas ("RNG") environmental attributes for our California Dairy Renewable Natural Gas segment, and biodiesel for our India Biodiesel segment.

	2025		2024		Inc/(dec)			% change
California Ethanol	$	3740,~~288~~726	$	4044,~~132~~934	$	(24,~~844~~208	)		(79.14	)%
California Dairy Renewable Natural Gas		3,~~051~~996		14,~~598~~250		~~1,453~~(254	)		90(6.90	)%
India Biodiesel		1114,~~904~~468		2432,~~831~~257		(1217,~~927~~789	)		(5255.1	)%
Total	$	5259,~~243~~190	$	6681,~~561~~441	$	(1422,~~318~~251	)		(2127.53	)%

California Ethanol. For the three months ended ~~June~~September 30, 2025, this segment generated ~~74.4~~77% of its revenue from sales of ethanol, and the rest from sales of WDG, Corn Oil, CDS, and CO₂. For the three months ended ~~June~~September 30, 2025, the Keyes Plant sold ~~13.8~~ 14.7 million gallons of ethanol at an average price of $2.01 13 per gallon and 91 96.0 thousand tons of WDG at an average price of ~~$86~~ $76.26 per ton, compared to sales during the three months ended ~~June~~September 30, 2024, when the Keyes Plant sold ~~14.8~~ 15.5 million gallons of ethanol at an average price of $12.9912 per gallon and ~~105~~ 106.0 thousand tons of WDG at an average price of ~~$89~~ $84.35 per ton. ~~Overall~~Revenue ~~revenue~~ decreased by ~~7.1~~9% primarily due to our scaling back of the Keyes Plant production rate to optimize yields, resulting in a decrease in sales volume of ethanol by 75% and WDG by 1310% along with a 10% decrease in the average price of WDG.

California Dairy Renewable Natural Gas. During the three months ended ~~June~~September 30, 2025, we sold ~~106.4~~ 114.0 thousand MMBtu ("million British thermal units") of RNG at an average price of $23.7545 per MMBtu, compared to the three months ended ~~June~~September 30, 2024, when we sold 88 86.0 thousand MMBtu of RNG at an average price of $2.1977 per MMBtu. During the three months ended ~~June~~September 30, 2025, we sold ~~763~~ 1.60 ~~thousand~~million D3 RINs at an average price of $2.60 37 per D3 RIN, compared to the three months ended ~~June~~September 30, 2024, when we sold ~~341~~ 935.3 thousand D3 RINs at an average price of $3.1737 per RIN. We have been generating LCFS credits associated with the RNG sales based on the default carbon intensity ("CI") of negative 150 while our individual dairy CI pathways were waiting for approval from the California Air Resources Board ("CARB"), which was received for seven of our dairies and effective during the three-month period ended September 30, 2025. During the period ended ~~June~~September 30, 2025, we sold 14 22.2 thousand LCFS credits at an average price of $5553.2550 each, compared to 520.0 thousand LCFS credits at an average price of $6443.7500 each during the period ended ~~June~~September 30, 2024.

India Biodiesel. In 2024 and 2025, all of our India sales of biodiesel were to government owned Oil Marketing Companies ("OMCs") pursuant to the OMC tender and allocation process. For the three months ended ~~June~~September 30, 2025 and 2024, we generated 80 96% of our India segment revenues from the sale of biodiesel, and ~~20% from other sales, compared to 96% of revenue from biodiesel, and~~ 4% from other sales ~~for the three months ended June 30, 2024~~. The decrease in revenues was primarily due to delays in receiving the tender contracts from ~~Oil Marketing Companies~~ OMCs and a change in the purchase price offered in the tender from cost-plus to a fixed price specified in the tender. We sold 912.4 5 thousand metric tons of biodiesel during the three months ended ~~June~~September 30, 2025, compared to 20 26.40 thousand metric tons of biodiesel sold during the three months ended ~~June~~September 30, 2024.

Cost of Goods Sold

Cost of goods sold consists primarily of feedstock, energy, chemicals, direct costs (principally labor and labor related costs), and overhead. Depending on the costs of these inputs in comparison to the sales price of our end products, our gross margins at any given time can vary from positive to negative. Overhead includes direct and indirect costs associated with plant operations, including the cost of repairs and maintenance, consumables, maintenance, on-site security, insurance, and depreciation.

We purchase our feedstock for California Ethanol from J.D. Heiskell based on daily market prices for corn plus costs of rail transportation, local basis, and a handling fee paid to J.D. Heiskell. The credit term for the corn purchased from J.D. Heiskell is one day, netted from our product sales. Cost of goods sold also includes the cost of electricity and natural gas, chemicals, maintenance, direct labor, depreciation, and freight.

We obtain the feedstock for producing RNG from dairy operators who lease us their land for construction of our digesters and supply our digesters with manure in liquid form. Our cost of feedstock is established by manure supply agreements based on the value of the environmental attributes and the number of cows at each dairy.

We procure several different feedstocks for the Kakinada Plant, including stearin, a non-edible feedstock, from neighboring natural oil processing plants. Raw material is received by truck and loaded at our vendor's nearby facilities. Credit terms vary by vendor. However, we generally receive 15 days of credit for the purchases. We purchase crude glycerin in the international market on letters of credit or advance payment terms as market prices become viable.

	2025		2024		Inc/(dec)			% change
California Ethanol	$	4142,~~094~~158	$	44,~~053~~849	$	(2,~~959~~691	)		(6.70	)%
California Dairy Renewable Natural Gas		2,~~196~~696		12,~~734~~353		~~462~~343			2614.6	%
India Biodiesel		1214,~~308~~394		2230,~~580~~361		(1015,~~272~~967	)		(4552.56	)%
Total	$	5559,~~598~~248	$	6877,~~367~~563	$	(1218,~~769~~315	)		(1823.76	)%

California Ethanol. We ground 4 5.70 million bushels of corn at an average cost of $65.42 95 per bushel during the three months ended ~~June~~September 30, 2025, compared to 5.2 5 million bushels of corn at an average cost of $6.36 07 per bushel during the three months ended ~~June~~September 30, 2024. The ~~6.7%~~ decrease in cost of goods sold for the three months ended ~~June~~September 30, 2025, is mainly due to the planned reduction in the quantity of corn ground along with a slight decrease in the average corn price per bushel.

(Tabular data in thousands, except par value and per share data)

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California Dairy Renewable Natural Gas. Cost of goods sold increased ~~includes~~between ~~dairy manure payments, equipment maintenance, and depreciation. The increase from~~ the ~~first~~third quarter of 2024 to the ~~first~~third quarter of 2025 ~~was~~as ~~primarily~~a ~~due~~result to of the ~~increase~~increased inmanure ~~the~~costs, ~~number~~digester ofmaintenance ~~operating~~expenses, and depreciation from additional digesters. placed into service

India Biodiesel. The decrease in cost of goods sold during the three months ended ~~June~~September 30, 2025, compared to ~~June~~September 30, 2024, was attributable to reduced biodiesel sales. ~~The~~resulting ~~average~~in ~~cost~~a of52% ~~feedstock~~decrease ~~used~~in totons ~~produce~~of ~~biodiesel~~feedstock ~~was $1~~used,~~165 per~~ ~~metric~~offset ~~ton~~by ~~during~~a ~~the~~7% ~~three~~cost ~~months~~increase ~~ended June~~in ~~30,~~feedstock ~~2025, compared to $924 per metric ton during the three months ended June 30, 2024~~used.

Gross profit (loss)

	2025			2024			Inc/(dec)			% change
California Ethanol	$	(31,~~806~~432	)	$	~~(3,921~~85	)	$	~~115~~(1,517	)		(21784.97	)%
California Dairy Renewable Natural Gas		~~855~~1,300			~~(136~~1,897	)		~~991~~(597	)		(~~728~~31.75	)%
India Biodiesel		~~(404~~74	)		21,~~251~~896			(21,~~655~~822	)		(~~117~~96.91	)%
Total	$	(~~3,355~~58	)	$	(13,~~806~~878	)	$	(13,~~549~~936	)		85(101.85	)%

California Ethanol. The decrease in gross ~~loss~~profit during the three months ended ~~June~~September 30, 2025, compared to the same period in 2024, was attributable primarily to ~~decreased~~decreases ~~corn~~in volumes ~~costs~~by 5% and 10% for ethanol and WDG respectively, coupled with a decrease of 10% in the average sales price of WDG, and partially offset by a 7.2% cost reduction.

California Dairy Renewable Natural Gas. The ~~increase~~decrease in gross profit for the three months ended ~~June~~September 30, 2025, compared to the same period in 2024, is due to the increase in ~~sales as~~costs aof ~~result~~goods of sold for the increased number of operating digesters.

India Biodiesel. The decrease in gross profit for the three months ended ~~June~~September 30, 2025, compared to the same period in 2024, reflects the decrease in the quantity of biodiesel sold, as well as a decrease in glycerin sold, coupled with ~~a 28%~~an increase in feedstock costs.

Operating (income)/expense and non-operating (income)/expense

	2025			2024			Inc/(dec)			% change
Selling, general and administrative		78,~~319~~450			117,~~800~~750			~~(4,481~~700	)		~~(38~~9.0	)%
Other expense (income):
Interest expense
Interest rate expense	$	11,~~235~~889		$	910,~~904~~096		$	1,~~331~~793			1317.48	%
Debt related fees and amortization expense		1,~~095~~061			1,~~820~~651			(~~725~~590	)		(3935.87	)%
Accretion and other expenses of Series A preferred units		2,~~032~~034			3,~~477~~267			(1,~~445~~233	)		(4137.67	)%
Other (income) expense		~~(1,112~~249	)		(181,225	)		(1,~~094~~474	)		~~6077~~(120.83	)%

SG&A expenses consist primarily of salaries and related expenses for employees, marketing expenses related to sales of ethanol and WDG in California Ethanol and biodiesel and other products in India Biodiesel, as well as professional fees, insurance, other corporate expenses, and related facility expenses. SG&A expenses as a percentage of revenue were 14% in the three months ended ~~June~~September 30, 2025, compared to 18 10% in the three months ended ~~June~~September 30, 2024. ~~The~~ ~~decrease in~~ SG&A expense ~~was~~remained ~~primarily due~~consistent tobetween ~~a one-time $3.6 million loss on an asset write-off in~~ the ~~three~~comparative ~~months ended June 30~~quarters, ~~2024,~~while ~~a $0.2~~revenue ~~million~~decreased ~~increase~~during ~~in rental income from subleases in~~ the three months ended ~~June~~September 30, 2025~~, and a reduction in legal, professional, and membership fees~~.

Other expenses consist primarily of interest and amortization expense on debt and accretion of the liability to repurchase biogas Series A Preferred Units. The cost of debt includes issuance of warrants as renewal fees. The fair value of stock and warrants are amortized as expenses, except when the extinguishment accounting method is applied, in which case refinanced debt costs are recorded as extinguishment expense. Interest expense and debt related fees and amortization increased in the three months ended ~~June~~September 30, 2025, due to higher variable interest rates and higher debt balances.

(Tabular data in thousands, except par value and per share data)

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~~Six~~Nine Months Ended ~~June~~September 30, 2025, Compared to ~~Six~~Nine Months Ended ~~June~~September 30, 2024

Revenues

	2025		2024		Inc/(dec)			% change
California Ethanol	$	75115,~~036~~762	$	76121,~~221~~155	$	(15,~~185~~393	)		(14.65	)%
California Dairy Renewable Natural Gas		59,~~494~~490		59,~~390~~640		~~104~~(150	)		(1.96	)%
India Biodiesel		1429,~~599~~067		5789,~~584~~841		(4260,~~985~~774	)		(7467.6	)%
Total	$	95154,~~129~~319	$	~~139~~220,~~195~~636	$	(4466,~~066~~317	)		(3130.71	)%

California Ethanol. For the ~~six~~nine months ended ~~June~~September 30, 2025, this segment generated 74 75% of its revenue from sales of ethanol, and the rest from sales of WDG, corn oil, CDS, and CO₂. During the ~~six~~nine months ended ~~June~~September 30, 2025, the Keyes plant sold 27 42.96 million gallons of ethanol at an average price of $2.00 04 per gallon and 280.0 ~~184~~ thousand tons of WDG at an average price of $8682.0066 per ton, compared to sales during the ~~six~~nine months ended ~~June~~September 30, 2024, when the Keyes plant sold 28 44.94 million gallons of ethanol at an average price of $1.8997 per gallon and ~~199~~ 305.0 thousand tons of WDG at an average price of $93 90.13 per ton. ~~This~~The California Ethanol segment's revenue decreased ~~slightly primarily~~ due to decrease in the quantities sold for ethanol and WDG along with a decrease in the WDG price.

California Dairy Renewable Natural Gas. During the ~~six~~nine months ended ~~June~~September 30, 2025, we sold ~~177~~ 291.3 thousand MMBtu ("million British thermal units") of RNG at an average price of $3.11 24 per MMBtu, compared to the ~~six~~nine months ended ~~June~~September 30, 2024, when we sold ~~148~~ 234.8 thousand MMBtu of RNG at an average price of $2.9488 per MMBtu. During the ~~six~~nine months ended ~~June~~September 30, 2025, we sold 1 2.2 million D3 RINs at an average price of $2.6150 per D3 RIN, compared to the ~~six~~nine months ended ~~June~~September 30, 2024, when we sold 12.1 0 million D3 RINs at an average price of $3.1123 per RIN. We have been generating LCFS credits associated with the RNG sales based on the default carbon intensity ("CI") of negative 150 while our individual dairy CI pathways were waiting for approval from the California Air Resources Board ("CARB"), which was received for seven of our dairies and effective during the three-month period ended September 30, 2025. During the ~~six~~nine months ended ~~June~~September 30, 2025, we sold 30 52.2 thousand LCFS credits at an average price of $6459.4580 each, compared to 43.0 23 thousand metric tons of LCFS credits at an average price of $6555.7316 each during the ~~six~~nine months ended ~~June~~September 30, 2024.

India Biodiesel. For the ~~six~~nine months ended ~~June~~September 30, 2025, the Kakinada Plant generated $923.5 million in revenue from sales of biodiesel, and $5.1 6 million from other sales. The India biodiesel plant generated $5485.7 8 million in revenue from biodiesel and $24.90 million in revenue from other sales during the same period in 2024. The segment's revenue decreased due to delays in ~~OMC's~~OMCs issuing tenders and the ~~associated~~OMCs ~~purchase~~use of fixed price contracts compared to higher volumes sold under cost plus contracts in the same period in 2024.

Cost of Goods Sold

	2025		2024		Inc/(dec)			% change
California Ethanol	$	83125,~~780~~938	$	85130,~~800~~649	$	(24,~~020~~711	)		(23.46	)%
California Dairy Renewable Natural Gas		47,~~334~~030		35,~~316~~669		1,~~018~~361			3024.70	%
India Biodiesel		1529,~~450~~844		5282,~~497~~858		(3753,~~047~~014	)		(7064.60	)%
Total	$	~~103~~162,~~564~~812	$	~~141~~219,~~613~~176	$	(3856,~~049~~364	)		(2625.97	)%

California Ethanol. We ground 914.4 million bushels of corn at an average cost of $6.53 33 per bushel during the ~~six~~nine months ended ~~June~~September 30, 2025, compared to 10 15.16 million bushels of corn at an average price of $6.35 25 per bushel during the ~~six~~nine months ended ~~June~~September 30, 2024. The slight decrease in cost of goods sold for the ~~six~~nine months ended ~~June~~September 30, 2025, is mainly due to the decrease in the quantity of the corn ground.

(Tabular data in thousands, except par value and per share data)

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California Dairy Renewable Natural Gas. Cost of goods sold includes dairy manure payments, equipment maintenance, and depreciation. The increase ~~from~~in 2025 ~~the~~was ~~second quarter~~primarily ~~of 2024~~due to ~~the~~increased ~~second~~manure ~~quarter~~costs, ~~of 2025~~maintenance ~~was~~costs, ~~primarily~~and ~~due~~depreciation tofrom the ~~increase~~increased ~~in the~~ number of operating digesters.

India Biodiesel. The decrease in cost of goods sold during the ~~six~~nine months ended ~~June~~September 30, 2025, compared to ~~June~~September 30, 2024, was attributable to a reduced use of feedstock due to reduced sales of biodiesel during the ~~six~~nine months ended ~~June~~September 30, 2025, of 921.40 thousand metric tons compared to 47 73.5 thousand metric tons of biodiesel sold during the ~~six~~nine months ended ~~June~~September 30, 2024.

Gross profit (loss)

	2025			2024			Inc/(dec)			% change
California Ethanol	$	(810,~~744~~176	)	$	(9,~~579~~494	)	$	~~835~~(682	)		~~(8.~~7.2	)%
California Dairy Renewable Natural Gas		12,~~160~~460			23,~~074~~971			(~~914~~1,511	)		(4438.1	)%
India Biodiesel		(~~851~~777	)		56,~~087~~983			(57,~~938~~760	)		(~~116~~111.71	)%
Total	$	(8,~~435~~493	)	$	(21,~~418~~460	)	$	(69,~~017~~953	)		~~248~~(681.87	)%

California Ethanol. The ~~decrease~~slight increase in gross loss between the ~~six~~nine months ended ~~June~~September 30, 2025, and the same period in 2024 was attributable primarily to a 4% decrease in the volume of ethanol sold and an 8% decrease in the ~~costs~~volume of WDG sold, along with an 8% decrease in the average price of ~~goods~~WDG sold, partially offset by a 4% decrease in costs.

California Dairy Renewable Natural Gas. The decrease in gross profit for the ~~six~~nine months ended ~~June~~September 30, 2025, compared to the same period in 2024 is due to the ~~decrease in sales and~~ increase in costs of goods sold, ~~primarily depreciation,~~ for the increased number of operating digesters along with a decrease in the average price of D3 RINs by 23%.

India Biodiesel. The decrease in gross profit during the ~~six~~nine months ended ~~June~~September 30, 2025, compared to the ~~six~~Nine months ended ~~June~~September 30, 2024 reflects ~~the~~ reduced sales in 2025 ~~the~~ and a 51% increase in feedstock costs.

Operating (income)/expense and non-operating (income)/expense

	2025			2024			Inc/(dec)			% change
Selling, general and administrative expenses		1726,~~794~~244			2028,~~650~~400			(2,~~856~~156	)		(137.86	)%
Other expense (income):
Interest expense
Interest rate expense	$	2234,~~253~~142		$	1829,~~996~~092			35,~~257~~050			17.14	%
Debt related fees and amortization expense		34,~~770~~831			34,~~241~~892			~~529~~(61	)		16(1.32	)%
Accretion and other expenses of Series A preferred units		46,~~311~~345			610,~~788~~055			(23,~~477~~710	)		(36.59	)%
Other income		(1,~~327~~078	)		49(1,176	)		~~(1,376~~98	)		(~~2808~~8.23	)%

SG&A expenses consist primarily of salaries and related expenses for employees, marketing expenses related to sales of ethanol and WDG in California Ethanol and biodiesel and other products in India Biodiesel, as well as professional fees, insurance, other corporate expenses, and related facility expenses. SG&A expenses as a percentage of revenue increased to 1917% in the ~~six~~nine months ended ~~June~~September 30, 2025, compared to 1513% in the ~~six~~nine months ended ~~June~~September 30, 2024. The overall decrease in SG&A expense was primarily due to a $3.6 million loss on an asset write-off in the ~~six~~ nine months ended ~~June~~September 30, 2024, $0.5 million reduction in digester-related administrative expenses, and $0.4 million reduction in stock compensation expenses; offset by a $21.21 million increase in ~~expenses~~professional ~~such~~fees, as$1.9 million increase in taxes, insurance, rent, utilities, supplies, and ~~services~~repairs, and $0.4 6 million increase in rental income from subleases in the ~~six~~nine months ended ~~June~~September 30, 2025.

Other expenses consist primarily of interest and amortization expense attributable to our debt and to accretion of biogas Series A Preferred Units. The cost of debt includes issuance of warrants as renewal fees. The fair value of stock and warrants are amortized asover ~~expenses,~~the ~~except~~life ~~when~~of the ~~extinguishment~~respective ~~accounting method is applied, in which case refinanced debt costs are recorded as extinguishment expense~~loan. Interest expense and debt related fees and amortization increased in the ~~six~~nine months ended ~~June~~September 30, 2025, due to higher variable interest rates and higher debt balances.

Liquidity and Capital Resources

Cash and Cash Equivalents

Cash and cash equivalents were $15.6 million at ~~June~~September 30, 2025, with $0.63 million held in our North American entities and $15.03 million in our India entity. ~~Our current ratio was 0.06 at June 30, 2025, compared to 0.31 at December 31, 2024.~~ We expect that our future available cash resources will be generated from operations, sales of equity, sales of tax credits, and new debt. Incurrence of new debt and the associated use of proceeds from future debt financings are subject to approval by our senior lender.

Liquidity

Cash and cash equivalents, current assets, current liabilities, and debt at the end of each period were as follows (in thousands):

	As of
	June 30, 2025		December 31, 2024
	September 30, 2025		December 31, 2024
Cash and cash equivalents	$	15,~~645~~584	$	898
Current assets (including cash, cash equivalents, and deposits)		2015,~~086~~554		44,696
Current and long-term liabilities (excluding all debt)		~~185~~192,~~039~~468		185,169
Current & long-term debt		~~344~~353,~~232~~503		338,061

Our principal sources of liquidity have been cash provided by the sale of equity, operations, and borrowings under various debt arrangements.

(Tabular data in thousands, except par value and per share data)

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We operate in a volatile market in which we have limited control over major components of input costs and product revenues. We are making investments in future facilities and facility upgrades that improve overall margins while lessening the impact of volatile markets. As such, we expect cash provided by operating activities to fluctuate in future periods primarily because of changes in the prices for corn, ethanol, WDG, DCO, CDS, biodiesel, waste fats and oils, glycerin, non-refined palm oil, natural gas, LCFS credits, and D3 RINs. To the extent that we experience periods in which the spread between ethanol prices and corn and energy costs narrow or the value of environmental attributes or tax credits is reduced, we require additional working capital to fund operations.

The India Biodiesel segment utilized its receivables financing facility during the quarter to support short-term liquidity needs. Although the facility was fully repaid by quarter-end, it remains available for future use. The Company believes this arrangement provides flexibility in managing cash flows while maintaining prudent risk oversight.

We are implementing several strategies to improve our cash flow from operations, as described in more detail in Note 16 Liquidity of our Consolidated Financial Statements in Item 1 of Part 1 above.

Senior Secured Debt

As of ~~June~~September 30, 2025, the outstanding balance of principal, interest and fees, net of discounts, on all Third Eye Capital Notes totals $~~225~~236.7 6 million. The maturity dates for the debts to Third Eye Capital are as follows:

● Due on demand: $4547.61 million

● March 1, 2026: $2728.7 million

● April 1, 2026: $~~152~~160.48 million

Third Eye Capital has provided a series of accommodating amendments to our debt facilities as described in further detail in Note 5. Debt of the Notes to Consolidated Financial Statements in this Form 10-Q. However, future amendments or accommodations will continue to be at the discretion of the lender. In the event our senior lender does not extend our debt, we would likely not have sufficient cash to pay the debt when due unless we are able to obtain alternative financing.

Change in Debt, Working Capital and Cash Flows

The following table describes the changes in current and long-term debt (in thousands) during the ~~six~~nine months ended ~~June~~September 30, 2025:

Increases to debt:
Accrued interest	$	2234,~~121~~086
Maturity date extension fee and other fees added to senior debt		2,410
Sub debt extension fees		680
Construction Loan draw		482
Change in debt issuance costs, net of amortization		799
Secured loans and Working capital loan draw		17,166
Construction Loan draw		1,228
Secured loans and Working capital loan draw		24,308
TEC short term promissory note		3,800
Total increases to debt				$	46,659
Equipment financing		51
Total increases to debt				$	67,362
Decreases to debt:
Principal, fees, and interest payments to senior lender	$	(15,276	)
Principal and interest payments and reductions to EB-5 promissory note		(4582	)
Reclassification of EB-5 broker promissory note		(2,595	)
Change in debt issuance costs, net of amortization		(174	)
Term Loan Payments		(7	)
Term Loan Payments		(5	)
Construction Term Loan Payments		(3,838	)
Construction Term Loan Payments		(2,489	)
Secured loans and Working capital loans payments		(29,768	)
Secured loans and Working capital loans payments		(19,689	)
Jessup purchase notes payments		(318	)
Jessup purchase notes payments		(175	)
Reclass to accounts payable for payment		(36	)
Reclass to accounts payable for payment		(40	)
Total decreases to debt				$	(51,920	)
Total decreases to debt				$	(40,488	)
Change in total debt				$	15,442
Change in total debt				$	6,171

(Tabular data in thousands, except par value and per share data)

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Working capital changes reflect (i) a $13 20.3 million decrease in inventories primarily due to restarting ~~shipment~~shipments of biodiesel to the OMCs after a delay in tenders; (ii) a $12.34 million decrease in accounts receivable and tax credit ~~sale~~ receivable primarily due to ~~our~~ receipt of ~~the~~$12.3 million in tax credit sale receivable, ~~proceeds;~~along ~~(iii)~~with ana $0.5 million increase in ~~trade~~North ~~accounts~~America ~~receivable~~and of a $0.9 6 million; ~~and~~decrease in the India Biodiesel segment; (iviii) a $0.9 million decrease in other current assets in the India Biodiesel segment.

Cash used in operating activities was $52.65 million, derived from a net loss of $4771.97 million, non-cash changes of $1623.64 million, and changes in operating assets and liabilities of $2545.8 million. The non-cash changes primarily consisted of: (i) $35.70 million in stock-based compensation expense, (ii) $4.7.0 million in depreciation expenses, (iii) $34.89 million in amortization of debt issuance costs and other intangible assets, (iv) $46.3 million in preferred unit accretion and other expenses of Series A Preferred Units. Cash increases related to changes in operating assets and liabilities consisted primarily of (i) a decrease in inventory of $1320.03 primarily due to the India biodiesel segment selling feedstock and biodiesel inventory, (ii) $12.3 million receipt from tax credit sales, (iii) $0.47 million reduction in ~~other~~accounts ~~assets~~receivable and prepaid expenses, (iv) $919.45 million increase in accrued interest expense and fees, and (v) $02.69 million increase in other liabilities. This was offset by (i) a $9.52 million decrease in accounts payable and (ii) an increase in ~~accounts~~other ~~receivable~~assets of $0.47 million.

Cash used in investing activities was $4.9.0 million, of which $4.9.4 million was primarily used for capital projects associated with production of RNG and energy efficiency projects in California offset by $0.4 million grants received~~, and $0~~.~~4 million was used for capital projects at the Kakinada Plant.~~

Cash provided by financing activities was $1116.34 million, consisting primarily of (i) $2129.32 million proceeds from borrowings, and (ii) $1825.27 million from sales of common stock and exercised stock options, offset by (i) $2535.47 million in repayments of borrowings, (ii) $2.2 million in payments on Series A Preferred financing, and (iii) $0.57 million in debt renewal, ~~and~~ waiver fee, and finance lease payments.

Our ongoing at-the-market stock sales registration allows us to sell shares of our common stock into the publicly traded market. During the three months ended ~~June~~September 30, 2025, we sold 72.69 million shares of common stock for net proceeds of $127.95 million net of commissions. During the ~~six~~nine months ended ~~June~~September 30, 2025, we sold ~~10.0~~13 million shares of common stock for net proceeds of $1825.0 5 million net of commissions, which is included in the cash provided by financing activities noted above.

Critical Accounting Policies and Estimates

Our discussion and analysis of financial condition and results of operations are based on our consolidated financial statements, which have been prepared in accordance with U.S. GAAP. The preparation of these financial statements requires us to make estimates and judgments that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported net sales and expenses for each period. We believe that of our most significant accounting policies and estimates, defined as those policies and estimates that we believe are the most important to the portrayal of our financial condition and results of operations and that require management’s most difficult, subjective or complex judgments, often as a result of the need to make estimates about the effects of matters that are inherently uncertain are: liquidity; debt covenant forecast; and recoverability of long-lived assets. 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, 2024.

Recently Issued Accounting Pronouncements

None reported beyond those disclosed in our Annual Report on Form 10-K for the year ended December 31, 2024.

Off Balance Sheet Arrangements

None.

Item 3. Quantitative and Qualitative Disclosures about Market Risk.

Not applicable.

Item 4. Controls and Procedures.

Evaluation of Disclosure Controls and Procedures.

Management, with the participation of our Chief Executive Officer (CEO) and Chief Financial Officer (CFO), carried out an evaluation of the effectiveness of the design and operation of our disclosure controls and procedures, as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the Exchange Act). Based on this evaluation, our CEO and CFO concluded that, although remediation plans were initiated to address the material weaknesses over financial reporting as identified in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2024, IT general controls along with certain internal controls over financial reporting were not effective to provide reasonable assurance that the information required to be disclosed by us in reports that we file or submit under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in Securities and Exchange Commission rules and forms, and is accumulated and communicated to our management, including our CEO and CFO, as appropriate, to allow timely decisions regarding required disclosure.

Changes in Internal Control over Financial Reporting.

As discussed in greater detail under Item 9A, Controls and Procedures, in our Annual Report on Form 10-K for the year ended December 31, 2024, we are executing our remediation plans to address the material weaknesses in our internal controls related to information technology general controls and information technology systems as well as documentation.

(Tabular data in thousands, except par value and per share data)

Table of Contents

PART II -- OTHER INFORMATION

Item 1. Legal Proceedings.

None.

Item 1A. Risk Factors.

Not applicable.

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

~~During~~In ~~the~~July ~~second quarter of~~ 2025, we issued ~~warrants to two subordinated lenders in connection with extensions of their debt. The warrants provided the right for the lenders to purchase~~ 113,000 ~~thousand~~ shares of Aemetis, Inc. common stock ~~for~~to ~~a period of~~ two ~~years at an exercise price of $0.01 per share. We then issued 113 thousand shares of common stock to the~~ lenders in connection with ~~their~~the lenders' exercise of ~~the~~ warrants issued during the ~~third~~prior quarter. The issuance of the ~~warrants~~shares ~~and~~was ~~the issuance of the common stock upon exercise of the warrants were~~ exempt from registration under Section 4(2) of the Securities Act of 1933, as amended, as issuances of securities not involving any public offering.

~~During~~In ~~the~~August ~~second quarter of~~ 2025, we issued 2920,~~240~~000 shares of Aemetis, Inc. common stock toas acompensation ~~vendor~~to ~~in connection with~~ a ~~services agreement at an effective value~~service ~~of $1~~provider.~~71 per~~ ~~share, which was the closing price on the Nasdaq market on the date prior to such issuance.~~ The issuance of the shares was exempt from registration under Section 4(2) of the Securities Act of 1933, as amended, as issuances of securities not involving any public offering.

In September 2025, we issued 19,686 shares of Aemetis, Inc. common stock to a vendor in connection with a services agreement at an effective value of $2.54 per share, which was the closing price on the Nasdaq market on the date prior to such issuance. The issuance of the shares was exempt from registration under Section 4(2) of the Securities Act of 1933, as amended, as issuances of securities not involving any public offering.

Item 3. Defaults Upon Senior Securities.

No unresolved defaults on senior securities occurred during the ~~six~~nine months ended ~~June~~September 30, 2025.

Item 4. Mine Safety Disclosures.

None.

Item 5. Other Information.

None.

Item 6. Exhibits.

31.1	Certifications pursuant to Rule 13a-14(a) or 15d-14(a) under the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2	Certifications pursuant to Rule 13a-14(a) or 15d-14(a) under the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1	Certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

32.2	Certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

101.INS *	Inline XBRL Instance Document

101.SCH *	Inline XBRL Taxonomy Extension Schema

101.CAL *	Inline XBRL Taxonomy Extension Calculation Linkbase

101.DEF *	Inline XBRL Taxonomy Extension Definition Linkbase

101.LAB *	Inline XBRL Taxonomy Extension Label Linkbase

101.PRE*	Inline XBRL Taxonomy Extension Presentation Linkbase

104	Cover Page Interactive Data File (formatted as inline XBRL and contained in Exhibit 101)

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SIGNATURES

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

	Aemetis, Inc.
Date: August 7, 2025	By:	/s/ Eric A. McAfee
Date: November 6, 2025	By:	/s/ Eric A. McAfee
		Eric A. McAfee Chair of the Board and Chief Executive Officer (Principal Executive Officer)

Date: August 7, 2025	By:	/s/ Todd A. Waltz
Date: November 6, 2025	By:	/s/ Todd Waltz
		Todd A. Waltz Executive Vice President and Chief Financial Officer (Principal Financial Officer)
		Todd Waltz Executive Vice President and Chief Financial Officer (Principal Financial Officer)

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