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Note 1 - Nature of Activities and Summary of Significant Accounting Policies | 3 Months Ended
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Mar. 31, 2023
Notes to Financial Statements |
Basis of Presentation and Significant Accounting Policies [Text Block] | 1. Nature of Activities and Summary of Significant Accounting Policies 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 an international renewable natural gas and renewable fuels company focused on the acquisition, development and commercialization of innovative negative carbon intensity products and technologies that replace traditional petroleum-based products. 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 reportable segments and are collectively represented by the “All Other” category. At Aemetis, our mission is to generate sustainable and innovative renewable fuel solutions that benefit communities and restore our environment. We do this by building a local circular bioeconomy utilizing agricultural waste to produce low carbon, advanced renewable fuels that reduce greenhouse gas ("GHG") emissions and improve air quality by replacing traditional petroleum-based products. 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 Wet Distillers Grains (“WDG”), Distillers Corn Oil (“DCO”), Carbon Dioxide (“CO₂”) and Condensed Distillers Solubles (“CDS”), all of which are sold as animal feed to local dairies and feedlots, with CO₂ sold to food, beverage, and industrial customers. We have several energy efficiency initiatives focused on significantly lowering the carbon intensity of our fuels. In the third quarter of 2022, a ZEBREXTM ethanol dehydration system completed installation and began commissioning, a key first step in the electrification of the Keyes Plant, which will significantly reduce the use of petroleum-based natural gas as process energy. During the last two weeks of December 2022, we undertook an extended maintenance cycle and accelerated the implementation of several important ethanol energy efficiency plant upgrades noted above. Our decision was partly driven by the high natural gas prices in Northern California during the period. Furthermore, after monitoring natural gas pricing and margin profitability, we decided to extend the maintenance cycle through the end of the first quarter of 2023. As such, revenues from the Keyes Plant during the first quarter of 2023 were limited to sales of stored inventory at the plant. With natural gas pricing in a reasonable range and the maintenance turn-around complete, we expect to restart the plant during the second quarter of 2023. Our California Dairy Renewable Natural segment, which consists of our subsidiary Aemetis Biogas LLC, “Aemetis Biogas” or “ABGL,” constructs and operates bio-methane anaerobic digesters at local dairies near the Keyes Plant (many of whom also purchase WDG produced by the Keyes Plant as animal feed); transports the biogas via pipeline to the Keyes Plant site; and converts the biogas to Renewable Natural Gas (“RNG”) which is then delivered to customers through the PG&E natural gas pipeline. The Aemetis Biogas network includes the Aemetis Biogas Central Dairy Project which operates 40 miles of completed biogas pipeline; six operating dairy digesters; five dairy digesters that are under construction; a centralized biogas-to-RNG conversion facility located at the Keyes Plant site; and a renewable natural gas interconnection with the PG&E utility gas pipeline. The dairy digesters are connected via an underground private pipeline owned by ABGL to a gas cleanup and compression unit at the Keyes Plant to produce dairy RNG. Upon receiving the bio-methane from the dairies, impurities are removed, and the bio-methane is converted to negative carbon intensity RNG that is injected into the statewide PG&E gas utility pipeline for use as transportation fuel or used as renewable process energy at the Keyes Plant. Our India Biodiesel segment owns and operates a plant in Kakinada, India (“Kakinada Plant”) with a nameplate capacity of 150 thousand metric tons per year, or about 50 million gallons per year, producing high quality distilled biodiesel and refined glycerin for customers in India and Europe. We believe the Kakinada Plant is one of the largest biodiesel production facilities in India on a nameplate capacity basis. The Kakinada Plant is capable of processing a variety of vegetable oils and animal fat waste feedstocks into biodiesel that meets international product standards. Our Kakinada Plant can also distill the crude glycerin byproduct from the biodiesel refining process into refined glycerin, which is sold to the pharmaceutical, personal care, paint, adhesive, and other industries. The Kakinada Plant shipped the tender offer orders placed during the third quarter of 2022 in the fourth quarter of 2022. As such, revenues from the Kakinada Plant during the first quarter of 2023 were limited to sales of stored inventory at the plant to private customers. In April 2023, Kakinada Plant was awarded a new tender offer to ship $34.0 million worth of biodiesel. Our All Other segment consists of: Carbon Zero biofuels production plants to produce renewable diesel and sustainable aviation fuel; Carbon Capture and Sequestration compression system and injection wells; a research and development facility in Minneapolis, Minnesota; and our corporate offices in Cupertino, California. Our Carbon Zero biofuels production plants are designed to produce low or negative carbon intensity sustainable aviation fuel (“SAF”) and renewable diesel fuel (“RD”) utilizing low carbon hydroelectric electricity, renewable hydrogen and non-edible renewable oils sourced from existing Aemetis biofuels plants and other sources. The first Carbon Zero plant is scheduled to be built in Riverbank, California at the 125-acre former Riverbank Army ammunition plant. The Riverbank plant is expected to utilize zero carbon hydroelectric and other renewable power available onsite to produce SAF, RD, and other byproducts. Our Carbon Capture subsidiary was established to build Carbon Capture and Sequestration (“CCS”) projects that generate LCFS and IRS 45Q tax credits by compressing and injecting CO₂ into deep wells which are monitored for emissions to ensure the long-term sequestration of carbon underground. In July 2022, Aemetis purchased 24 acres located on the Riverbank Industrial Complex site in Riverbank, California to develop a CCS injection well. Basis of Presentation and Consolidation. These consolidated financial statements include the accounts of Aemetis. Additionally, 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. ABGL was assessed to be a VIE and through the Company’s ownership interest in all of the outstanding common stock, the Company has been determined to be the primary beneficiary and accordingly, the assets, liabilities, and operations of ABGL are consolidated into those of the Company. All intercompany balances and transactions have been eliminated in consolidation. The accompanying consolidated condensed balance sheet as of March 31, 2023, the consolidated condensed statements of operations and comprehensive loss for the three months ended March 31, 2023 and 2022, the consolidated condensed statements of cash flows for the three months ended March 31, 2023 and 2022, and the consolidated condensed statements of stockholders’ deficit for the three months ended March 31, 2023 and 2022 are unaudited. The consolidated condensed balance sheet as of December 31, 2022, was derived from the 2022 audited consolidated financial statements and notes thereto. The consolidated condensed financial statements in this report should be read in conjunction with the 2022 audited consolidated financial statements and notes thereto included in the Company’s annual report on Form 10-K for the year ended December 31, 2022. 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 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 months ended March 31, 2023 and 2022 have been prepared on the same basis as the audited consolidated statements as of and for the year ended December 31, 2022 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 months ended March 31, 2023 are not necessarily indicative of the operating results for any subsequent quarter, for the full fiscal year or any future periods. Use of Estimates. The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, revenues, and expenses during the reporting period. To the extent there are material differences between these estimates and actual results, the Company’s consolidated financial statements will be affected. Revenue Recognition. We derive revenue primarily from sales of ethanol and related co-products in North America, and biodiesel and refined glycerin in India pursuant to supply agreements and purchase order contracts. We assessed the following criteria under the Accounting Standards Codification (“ASC”) 606 guidance: (i) identify the contracts with customer, (ii) identify the performance obligations in the contract, (iii) determine the transaction price, (iv) allocate the transaction price to the performance obligations, and (v) recognize revenue when the entity satisfies the performance obligations. California Ethanol: On May 13, 2020, we entered into an amendment to the Corn Procurement and Working Capital Agreement with J.D. Heiskell (the “Corn Procurement and Working Capital”), pursuant to which we buy all corn from J.D. Heiskell and sell all WDG and corn oil we produce to J.D. Heiskell. Effective October 1, 2021, we entered into Fuel Ethanol Purchase and Sale Agreement with Murex LLC (“Murex”), in which we sell all our ethanol to Murex through individual sales transactions. Given the similarity of the individual sales transactions with Murex, we have assessed them as a portfolio of similar contracts. The performance obligation is satisfied by delivery of the physical product to one of our customer’s contracted trucking companies. Upon delivery, the customer has the ability to direct the use of the product and receive substantially all of its benefits. The transaction price is determined based on daily market prices negotiated by Murex for ethanol and by our marketing partner A.L. Gilbert Company (“A.L. Gilbert”) for WDG. The transaction price is allocated to one performance obligation. The below table shows our sales in our California Ethanol segment by product category:
|  | For the three months ended March 31, |
|  | 2023 |  |  | 2022 |
Ethanol sales |  | $ | 368 |  |  | $ | 37,896 |
Wet distiller's grains sales |  |  | - |  |  |  | 11,517 |
Other sales |  |  | 107 |  |  |  | 2,628 |
|  | $ | 475 |  |  | $ | 52,041 |
We have elected to adopt the practical expedient that allows for ignoring the significant financing component of a contract when estimating the transaction price when the transfer of promised goods to the customer and customer payment for such goods are expected to be within one year of contract inception. Further, we have elected to adopt the practical expedient in which incremental costs of obtaining a contract are expensed when the amortization period would otherwise be less than one year. For ethanol, we only have customer relationships with Murex, hence the principal and agent criteria are not applied. However, we are still buying corn and selling WDG and corn oil to J.D.Heiskell. We analyzed the principal versus agent relationship criteria below. We consider the purchase of corn as a cost of goods sold and the sale of WDG and, corn oil, upon trucks leaving the Keyes Plant, as revenue on the basis that (i) we control and bear the risk of gain or loss on the processing of corn which is purchased at market prices into ethanol and (ii) we have legal title to the goods during the processing time. The pricing for both WDG and corn oil is set independently. Revenues from WDG and corn oil are billed net of the related transportation and marketing charges. The transportation component is accounted for in cost of goods sold and the marketing component is accounted for in sales, general and administrative expense. Transportation and marketing charges are known within days of the transaction and are recorded at the actual amounts. We have elected an accounting policy under which these charges have been treated as fulfillment activities provided after control has transferred. As a result, these charges are recognized in cost of goods sold and selling, general and administrative expenses, respectively, when revenue is recognized. Revenues are recorded at the gross invoiced amount. Hence, we are the principal in California Ethanol segment where our customer and vendor may be the same. California Dairy Renewable Natural Gas: In December 2018, we utilized our relationships with California’s Central Valley dairy farmers by signing leases and raising funds to construct dairy digesters, a 40 mile pipeline, a centralized biogas cleanup and a renewable natural gas interconnection with PG&E pipeline. We are currently producing RNG from six digesters connected to 40 miles of pipeline, then flowing this gas to our RNG cleanup hub and delivering the gas through an interconnect to the PG&E pipeline at the Keyes Plant. The RNG upgrade unit at the Keyes Plant is designed deliver utility-grade RNG for sale as transportation fuel to California customers via pipeline delivery. We have 30 signed agreements with dairies to construct dairy digesters. Our revenue development strategy for the Dairy Renewable Natural Gas segment relies upon continuing to collect bio-methane gas from the existing dairy digesters, continuing to build out the network of dairy digesters, extending the pipeline in Northern California to grow the supply of RNG available for sale and utilizing the biogas-to-RNG upgrade unit to distribute utility-grade RNG to customers statewide. We plan to store the RNG until the LCFS credit pathway for each dairy has been established, after which we will sell the stored gas by delivering it into the utility gas pipeline . As of March 31, 2023 , we have 31.0 thousand MMBtu of RNG in storage. The RNG in storage is recorded at the lower of cost and net realizable value. The value per LCFS as of March 31, 2023 was $70 per metric ton and the value per D3 Cellulosic RIN was $1.96; for an estimated market value $53.37 per MMBtu, assuming a CI score of -427. India Biodiesel: We sell products pursuant to purchase orders (written or verbal) or by contract with governmental or international parties, in which performance is satisfied by delivery and acceptance of the physical product. Given that the contracts are sufficiently similar in nature, we have assessed these contracts as a portfolio of similar contracts as allowed under the practical expedient. Doing so does not result in a materially different outcome compared to individually accounting for each contract. All domestic and international deliveries are subject to certain specifications as identified in contracts. The transaction price is determined daily based on reference market prices for biodiesel, refined glycerin, and PFAD net of taxes. Transaction price is allocated to one performance obligation. The below table shows our sales in our India Biodiesel segment by product category:
|  | For the three months ended March 31, |
|  | 2023 |  |  | 2022 |
Biodiesel sales |  | $ | 1,190 |  |  | $ | - |
Other sales |  |  | 280 |  |  |  | 8 |
|  | $ | 1,470 |  |  | $ | 8 |
In India, we also assessed principal versus agent criteria as we buy our feedstock from our customers and process and sell finished goods to those same customers in certain contractual agreements. In those cases, we receive the legal title to feedstock from our customers once it is on our premises. We control the processing and production of biodiesel based on contract terms and specifications. The pricing for both feedstock and biodiesel is set independently. We hold the title and risk to biodiesel according to agreements when we enter into in these situations. Hence, we are the principal in India sales scenarios where our customer and vendor may be the same. Cost of Goods Sold. Cost of goods sold includes those costs directly associated with the production of revenues, such as raw material consumed, factory overhead and other direct production costs. During periods of idle plant capacity, costs otherwise charged to cost of goods sold are reclassified to selling, general and administrative expense. Shipping and Handling Costs. Shipping and handling costs are classified as a component of cost of goods sold in the accompanying consolidated statements of operations. Research and Development. Research and development costs are expensed as incurred, unless they have alternative future uses to the Company. Cash, Cash Equivalents, and Restricted Cash. The Company considers all highly liquid investments with an original maturity of three months or less to be cash equivalents. The Company maintains cash balances at various financial institutions domestically and abroad. The Federal Deposit Insurance Corporation insures domestic cash accounts. The Company’s accounts at these institutions may at times exceed federally insured limits. The Company has not experienced any losses in such accounts. Amounts included in restricted cash represent those required to be set aside by the Construction Loan Agreement with Greater Nevada Credit Union ("GNCU") and will be released upon approval by GNCU. The following table provides a reconciliation of cash, cash equivalents and restricted cash reported within the Consolidated Balance Sheet to the total of the same such amounts shown in the statement of cash flows.
|  | As of
|  | March 31, 2023 |  | December 31, 2022
Cash and cash equivalents |  | $ 4,131 |  | $ 4,313
Restricted cash included in other current assets |  | 127 |  | 725
Restricted cash included in other assets |  | 1,961 |  | 1,961
Total cash, cash equivalents, and restricted cash shown in the statement of cash flows |  | $ 6,219 |  | $ 6,999
Accounts Receivable. The Company sells ethanol and WDG through third-party marketing arrangements generally without requiring collateral directly to customers on a variety of terms including advanced payment terms, based on the size and creditworthiness of the customer. DCO is marketed and sold to A.L. Gilbert and other customers under the J.D. Heiskell Purchasing Agreement. The Company sells CDS directly to customers on standard 30 day payment terms. The Company sells biodiesel, glycerin, and processed natural oils to a variety of customers and may require advanced payment based on the size and creditworthiness of the customer. Usually, invoices are due within 30-days on net terms. Accounts receivables consist of product sales made to large creditworthy customers. Trade accounts receivable are presented at original invoice amount, net of any allowance for doubtful accounts. We did not reserve any balance for allowances for doubtful accounts as of March 31, 2023 and December 31, 2022. The Company maintains an allowance for doubtful accounts for balances that appear to have specific collection issues. The collection process is based on the age of the invoice and requires attempted contacts with the customer at specified intervals. If, after a specified number of days, the Company has been unsuccessful in its collection efforts, a bad debt allowance is recorded for the balance in question. Delinquent accounts receivables are charged against the allowance for doubtful accounts once un-collectability has been determined. The factors considered in reaching this determination are the apparent financial condition of the customer and the Company’s success in contacting and negotiating with the customer. If the financial condition of the Company’s customers were to deteriorate, additional allowances may be required. Inventories. Finished goods, raw materials, and work-in-process inventories are valued using methods which approximate the lower of cost (first-in, first-out) or net realizable value (“NRV”). Distillers’ grains and related products are stated at NRV. In the valuation of inventories, NRV is determined as estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. Variable Interest Entities. We determine at the inception of each arrangement whether an entity in which we have made an investment or in which we have other variable interests in is considered a variable interest entity (“VIE”). We consolidate VIEs when we are the primary beneficiary. The primary beneficiary of a VIE is the party that meets both of the following criteria: (1) has the power to make decisions that most significantly affect the economic performance of the VIE; and (2) has the obligation to absorb losses or the right to receive benefits that in either case could potentially be significant to the VIE. Periodically, we assess whether any changes in our interest or relationship with the entity affects our determination of whether the entity is still a VIE and, if so, whether we are the primary beneficiary. If we are not the primary beneficiary in a VIE, we account for the investment or other variable interests in a VIE in accordance with applicable U.S. GAAP. Property, Plant and Equipment. Property, plant, and equipment are carried at cost less accumulated depreciation after assets are placed in service and are comprised primarily of plant and buildings, furniture, machinery, equipment, land, and biogas dairy digesters. Capital expenses for in-process project are accumulated in construction in progress and will be capitalized and depreciated once the capital projects are finished and are in service. The Company’s plant in Goodland, Kansas (the ”Goodland Plant”) is partially completed and is not ready for operation. It is the Company’s policy to depreciate capital assets over their estimated useful lives using the straight-line method. The Company evaluates the recoverability of long-lived assets with finite lives in accordance with ASC Subtopic 360-10-35 Property Plant and Equipment—Subsequent Measurements, which requires recognition of impairment of long-lived assets whenever events or changes in circumstances indicate that the carrying amount of an asset group may not be recoverable. When events or changes in circumstances indicate that the carrying amount of an asset group may not be recoverable, based on estimated undiscounted cash flows, the impairment loss would be measured as the difference between the carrying amount of the assets and its estimated fair value. The Company has not recorded any impairment during the three months ended March 31, 2023 and 2022. California Energy Commission Low-Carbon Fuel Production Program. The Company has been awarded $4.2 million in matching grants from the California Energy Commission Low-Carbon Fuel Production Program (“LCFPP”). The LCFPP grant reimburses the Company for costs to design, procure, and install processing facility to clean-up, measure and verify negative-carbon intensity dairy renewable natural gas fuel at the production facility in Keyes, California. The Company has received $3.8 million from the LCFPP as of March 31, 2023, as reimbursement for actual costs incurred. Due to the uncertainty associated with the approval process under the grant program, the Company recognized the grant as a reduction of costs in the period when payment is received. In October 2020, the Company was awarded $7.8 million in matching grants from the CDFA Dairy Digester Research and Development program. The CDFA grant reimburses the Company for costs required to permit and construct six of the Company’s biogas capture systems under contract with central California dairies. The Company has received $3.9 million from the CDFA 2020 grant program as of March 31, 2023, as reimbursement for actual costs incurred. Due to the uncertainty associated with the approval process under the grant program, the Company recognized the grant as a reduction of costs in the period when payment is received. California Energy Commission Low Carbon Advanced Ethanol Grant Program. In May 2019, the Company was awarded the right to receive reimbursements from the California Energy Commission Community-Scale and Commercial-Scale Advanced Biofuels Production Facilities grant under the Alternative and Renewable Fuel and Vehicle Technology Program in an amount up to $5.0 million (the “CEC Reimbursement Program”) in connection with the Company’s expenditures toward the development of the Riverbank Carbon Zero Facility. To comply with the guidelines of the CEC Reimbursement Program, the Company must make a minimum of $7.9 million in matching contributions to the Riverbank project. The Company receives funds under the CEC Reimbursement Program for actual expenses incurred up to $5.0 million as long as the Company makes the minimum matching contribution. Given that the Company has not made the minimum matching contribution, the grant for reimbursement of capital expenditures of $1.7 million is presented with long-term liabilities as of March 31, 2023, and December 31, 2021. Due to the uncertainty associated with meeting the minimum matching contribution, the reimbursement will be recognized when the Company makes the minimum matching contribution. U.S. Department of Food and Agriculture Forest Service Grant. Aemetis Advanced Products Keyes (“AAPK”) has been awarded $245 thousand in matching grants from the U.S. Department of Food and Agriculture Forest Service (“US Forest Service”) under the Wood Innovation and Community Wood program. The grant reimburses the Company for continued development of technologies and processes to valorize forest waste for the production of cellulosic ethanol. AAPK has received $216 thousand from the US Forest Service as reimbursement for actual allowable program costs incurred through March 31, 2023. California Energy Commission Grant for Solar Microgrid, DSC and Battery Backup System. Aemetis Advanced Fuels Keyes (“AAFK”) has been awarded an $8.0 million grant to design, construct and commission a grid-connected 1.56 MW photovoltaic microgrid and 1.25MW/2.5MWh Battery Energy Storage System integrated with an artificial intelligence-driven distributed control system (DCS). The Company has made the required $1.6 million in matching contributions to qualify to receive grant reimbursements. AAFK received $4.2 million in grant funds from this program as reimbursement for actual expenditures incurred through March 31, 2023. Due to the uncertainty associated with the approval process under the grant program, the Company recognized the grant as a reduction of costs in the period when payment is received. California Department of Forestry and Fire Protection Grant. AAPK has been awarded $2 million in matching grants from the CAL FIRE Business and Workforce Development Grant Program (“CAL Fire”) in May 2022. This CAL Fire grant program reimburses AAPK for costs to design, construct, and commission a 2 million gallon per year cellulosic ethanol facility able to convert conifer biomass from forested regions of the Sierra Nevada into an ultra‐low carbon biofuel derived from 100% forest biomass (“CAL Fire Conversion Program”). AAPK must contribute $5.8 million in cost share contributions to the project to receive grant proceeds. AAPK has received no grant funds from the CAL Fire Conversion Program as reimbursement for actual costs through March 31, 2023. California Department of Forestry and Fire Protection Grant. AAPK was awarded $500 thousand in grants from CAL Fire in May 2022. This CAL Fire grant program reimburses AAPK for costs to advance a new‐to‐the world technology that circumvents current limitations surrounding the extraction of cellulosic sugars by pioneering a novel route for deconstructing woody biomass using ionic liquids (“CAL Fire Extraction Program”). AAPK has received no grant funds from the CAL Fire Extraction Program as reimbursement for actual costs through March 31, 2023. U.S Forest Service Community Wood Grant. Aemetis Advanced Products Riverbank (“AAPR”) was awarded $642 thousand in matching grants from the U.S Forest Service Wood Innovations Program (“USFS”) in May 2022. The USFS grant program reimburses AAPR for costs to design, construct, and commission a plant to produce cellulosic ethanol using preliminary research and development in partnership with the Joint Bioenergy Institute (JBEI). USFS grant funds will be used to complete the FEL-3 design phase of the entire process, construct a biomass pretreatment unit to extract sugars at the Aemetis Riverbank site and ferment sugars into ethanol at the Keyes Plant. AAPR must contribute $2.4 million in cost share contributions to the project to receive grant proceeds. AAPK has received no grant funds from the USFS grant program as reimbursement for actual costs through March 31, 2023. California Energy Commission Grant for Mechanical Vapor Recompression System. Aemetis Advanced Fuels Keyes (“AAFK”) has been awarded a $6.0 million grant to design, construct and commission a mechanical vapor recompression (MVR) system. The additional evaporation stages will eliminate natural gas consumption and related greenhouse gas emissions in the evaporation portion of the process by installing metering equipment and software to monitor and optimize the plant’s energy consumption. The MVR system will compress vapor to a higher pressure and temperature so that it can be recycled multiple times as steam heat in the evaporation process, which will dramatically reduce natural gas use. The grant requires $5.3 million in matching contributions. AAFK has received no grant funds from this program as reimbursement for actual expenditures incurred through March 31, 2023. Due to the uncertainty associated with the approval process under the grant program, the Company will recognize future grant proceeds received as a reduction of costs in the period when payment is received. Pacific Gas and Electric SEM Manufacturer’s Incentive Program. During the fourth quarter of 2022, AAFK received $374 thousand in PG&E SEM Incentive Program reimbursements for installing more efficient beer feed heat exchangers. Third party consultants verified the reduction in natural gas usages from the new heat exchangers to obtain the incentive program funds. California Energy Commission PG&E A2313 Pipeline Interconnection Grant. The Company has received $5 million in matching grants from the California Energy Commission PG&E A2313 Pipeline Interconnection program (“CEC PG&E Pipeline Interconnect”) during the quarter ended March 31, 2023. The CEC PG&E Pipeline Interconnect grant reimburses the Company for actual costs to design, procure, and install facility and pipeline to interconnect renewable natural gas pipeline with the PG&E utility pipeline. In October 2022 the Company successfully connected and commissioned pipeline interconnection with the PG&E utility pipeline. After three months of renewable natural gas delivery verified the interconnection, the CEC PG&E program funds were released. The Company has received all $5 million available from the PG&E program as reimbursement for actual costs incurred as of March 31, 2023. Given the nature of funds received as reimbursement for actual costs incurred, the funds were applied against the actual costs. Basic and Diluted Net Loss per Share. Basic net loss per share is computed by dividing net loss attributable to common shareholders by the weighted average number of common shares outstanding for the period. Diluted net loss per share reflects the dilution of common stock equivalents such as options, convertible preferred stock, debt, and warrants to the extent the impact is dilutive. As the Company incurred net losses for the three months ended March 31, 2023 and 2022, potentially dilutive securities have been excluded from the diluted net loss per share computations as their effect would be anti-dilutive. The following table shows the number of potentially dilutive shares excluded from the diluted net loss per share calculation as of March 31, 2023 and 2022:
|  | As of |
|  | March 31, 2023 |  |  | March 31, 2022 |
Series B preferred (post split basis) |  |  | 127 |  |  |  | 127 |
Common stock options and warrants |  |  | 6,125 |  |  |  | 4,774 |
Debt with conversion feature at $30 per share of common stock |  |  | 1,246 |  |  |  | 1,223 |
Total number of potentially dilutive shares excluded from the diluted net (loss) per share calculation |  |  | 7,498 |  |  |  | 6,124 |
Comprehensive Income (Loss). ASC 220 Comprehensive Income (Loss) requires that an enterprise report, by major components and as a single total, the change in its net assets from non-owner sources. The Company’s other comprehensive loss and accumulated other comprehensive loss consists solely of cumulative currency translation adjustments resulting from the translation of the financial statements of its foreign subsidiary. The investment in this subsidiary is considered indefinitely invested overseas, and as a result, deferred income taxes are not recorded related to the currency translation adjustments. Foreign Currency Translation/Transactions. Assets and liabilities of the Company’s non-U.S. subsidiary that operates in a local currency environment, where that local currency is the functional currency, are translated into U.S. dollars at exchange rates in effect at the balance sheet date and the resulting translation adjustments directly recorded to a separate component of accumulated other comprehensive loss. Income and expense accounts are translated at average exchange rates during the year. Transactional gains and losses from foreign currency transactions are recorded in other (income) expense, net. Segments. Operating segments are defined as components of an enterprise about which separate financial information is available that is evaluated regularly by the chief operating decision maker, or decision-making group, in deciding how to allocate resources and in assessing performance. The Company further evaluates its operating segments to determine its reportable segments. Aemetis recognizes three reportable segments “California Ethanol”, “California Dairy Renewable Natural Gas”, and “India Biodiesel.” The “California Ethanol” reportable segment includes the Company’s 65 million gallon per year Keyes plant and the adjacent land leased for the production of CO₂. The “California Dairy Renewable Natural Gas” reportable segment includes the dairy digesters, pipeline and gas condition hub for the production of biogas from dairies near Keyes, California. The “India Biodiesel” reportable segment includes the Company’s 50 million gallon per year nameplate capacity biodiesel manufacturing Kakinada Plant, the administrative offices in Hyderabad, India, and the holding companies in Nevada and Mauritius. The Company’s biodiesel is marketed and sold primarily to customers in India through brokers and by the Company directly. The Company has additional operating segments that were determined not to be reportable segments, including the Carbon Zero biofuels production plants to produce renewable diesel and sustainable aviation fuel; the Carbon Capture and Sequestration compression system and injection wells; a research and development facility in Minneapolis, Minnesota; and our corporate offices in Cupertino, California. Fair Value of Financial Instruments. Financial instruments include accounts receivable, accounts payable, accrued liabilities, current and non-current portion of subordinated debt, notes receivable, notes payable, Series A preferred units, and long-term debt. Due to the unique terms of our notes payable and long-term debt and the financial condition of the Company, the fair value of the debt is not readily determinable. The fair value determined using level 3 inputs, of all other current financial instruments is estimated to approximate carrying value due to the short-term nature of these instruments. Share-Based Compensation. The Company recognizes share-based compensation expense in accordance with ASC 718 Stock Compensation requiring the Company to recognize expenses related to the estimated fair value of the Company’s share-based compensation awards at the time the awards are granted, adjusted to reflect only those shares that are expected to vest. Commitments and Contingencies. The Company records and/or discloses commitments and contingencies in accordance with ASC 450 Contingencies. ASC 450 applies to an existing condition, situation or set of circumstances involving uncertainty as to possible loss that will ultimately be resolved when one or more future events occur or fail to occur. Convertible Instruments. The Company evaluates the impacts of convertible instruments based on the underlying conversion features. Convertible instruments are evaluated for treatment as derivatives that could be bifurcated and recorded separately. Any beneficial conversion feature is recorded based on the intrinsic value difference at the commitment date. Debt Modification Accounting. The Company evaluates amendments to its debt in accordance with ASC 470-60 Troubled Debt Restructuring and ASC 470-50 Debt–Modification and Extinguishments for modification and extinguishment accounting. The evaluation for troubled debt restructuring includes assessing qualitative and quantitative factors such as whether the creditor granted a concession and if the Company is experiencing financial difficulties. The quantitative analysis includes the calculation of the post-restructuring effective interest rate by projecting cash flows on the new terms comparing this calculation to the terms of prior amendments. If the post restructuring effective interest rate is less than the prior terms effective interest rate, we assess this as having been granted a concession. The troubled debt restructuring accounting would be applied to any debt which meets the qualitative factors and quantitative factor of concession granted. If the debt would not fall into Troubled Debt Restructuring then we apply ASC 470-50 Debt-Modification and Extinguishment. This evaluation includes comparing the net present value of cash flows of the new debt to the old debt to determine if changes greater than 10 percent occurred. In instances where the net present value of future cash flows changed more than 10 percent, the Company applies extinguishment accounting and determines the fair value of its debt based on factors available to the Company. For a complete summary of the Company’s significant accounting policies, please refer to the Company’s audited financial statements and notes thereto for the years ended December 31, 2022 and 2021 included in the Company’s Annual Report on Form 10-K filed with the Securities and Exchange Commission on March 9, 2023.

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