As filed with the Securities and Exchange Commission on April 16, 2025.

Registration No. 333-284257

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

__________________________________

POST EFFECTIVE AMENDMENT NO. 1

TO
FORM S-1
REGISTRATION STATEMENT
UNDER
THE SECURITIES ACT OF 1933

__________________________________

ALEANNA, INC.
(Exact name of registrant as specified in its charter)

__________________________________

Delaware |  | 1311 |  | 98-1582153
(State or other Jurisdiction of Incorporation Or Organization) |  | (Primary Standard Industrial Classification Code Number) |  | (I.R.S. Employer Identification Number)

300 Crescent Court, Suite 1860
Dallas, TX 75201
(469) 396-2200
(Address, Including Zip Code, and Telephone Number, Including Area Code, of Registrant’s Principal Executive Offices)

__________________________________

Tristan Yopp
Chief Financial Officer
300 Crescent Court, Suite 1860
Dallas, TX 75201
(469) 396-2200
(Name, Address, Including Zip Code, and Telephone Number, Including Area Code, of Agent for Service)

__________________________________

Copies of all communications, including communications sent to agent for service, should be sent to:

Jennifer T. Wisinski, Esq.
Stephen W. Grant, Jr., Esq.
Haynes and Boone, LLP
2801 N. Harwood Ave.
Suite 2300
Dallas, TX 75201
Tel: (214) 651-5000

__________________________________

Approximate date of commencement of proposed sale to the public:
From time to time after the effective date hereof.

If any of the securities being registered on this Form are to be offered on a delayed or continuous basis pursuant to Rule 415 under the Securities Act of 1933, check the following box. ☒

If this Form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act, please check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. ☐

If this Form is a post-effective amendment filed pursuant to Rule 462(c) under the Securities Act, please check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. ☐

If this Form is a post-effective amendment filed pursuant to Rule 462(d) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. ☐

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 7(a)(2)(B) of the Securities Act. ☐

The Registrant hereby amends this Registration Statement on such date or dates as may be necessary to delay its effective date until the registrant shall file a further amendment which specifically states that this Registration Statement shall thereafter become effective in accordance with Section 8(a) of the Securities Act of 1933 or until the registration statement shall become effective on such date as the Securities and Exchange Commission, acting pursuant to said Section 8(a), may determine.

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EXPLANATORY NOTE

This Post-Effective Amendment No. 1 (this “Post-Effective Amendment”) relates to the registration statement on Form S-1 (File No. 333-284257), initially filed by AleAnna, Inc., a Delaware corporation (the “Company”), with the Securities and Exchange Commission (the “Commission”) on January 13, 2025 and declared effective by the Commission on January 23, 2025 (the “Registration Statement”).

This Post-Effective Amendment is being filed pursuant to Section 10(a)(3) of the Securities Act of 1933, as amended (the “Securities Act”) to update the Registration Statement to include, among other things, the financial statements of the Registrant as of and for the year ended December 31, 2024, which was filed with the Commission on March 31, 2025, as part of the Registrant’s Annual Report on Form 10-K.

This Post-Effective Amendment covers only the resale, from time to time, of up to 11,225,969 shares of Class A common stock, par value $0.0001 per share, of the Company (the “Class A Common Stock”) issuable upon exercise of an aggregate of 11,225,969 warrants (the “Public Warrants”), each of which is exercisable at a price per share of $11.50 per share, issued as part of units in the initial public offering of Swiftmerge Acquisition Corp. The Company previously paid to the Commission the entire registration fee relating to the shares of Class A Common Stock that are the subject of this Post-Effective Amendment. The Company paid a fee of $19,807.31 in connection with the registration of the shares of Class A Common Stock in connection with the Registration Statement.

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The information in this preliminary prospectus is not complete and may be changed. These securities may not be sold until the registration statement filed with the Securities and Exchange Commission is effective. This preliminary prospectus is not an offer to sell nor does it seek an offer to buy these securities in any jurisdiction where the offer or sale is not permitted.

SUBJECT TO COMPLETION, DATED APRIL 16, 2025

PRELIMINARY PROSPECTUS

ALEANNA, INC.

11,225,969 Shares of Class A Common Stock Issuable Upon Exercise of Warrants

This prospectus relates to the issuance by us of up to 11,225,969 shares of Class A common stock, par value $0.0001 per share, of AleAnna, Inc. (the “Class A Common Stock”) issuable upon exercise of an aggregate of 11,225,969 warrants (the “Public Warrants”), each of which is exercisable at a price per share of $11.50 per share, issued as part of units in the initial public offering of Swiftmerge Acquisition Corp.

To the extent the Public Warrants are exercised for cash, we will receive cash proceeds from the exercise of the Public Warrants. See “Description of Securities.” We believe the likelihood that the holders of the Public Warrants will exercise their Public Warrants, and therefore the amount of cash proceeds that we would receive, is dependent upon the trading price of our Class A Common Stock. If the trading price for our Class A Common Stock is less than $11.50 per share, we believe holders of our Public Warrants are unlikely to exercise their Public Warrants. Conversely, these holders are more likely to exercise their Public Warrants the higher the price of our Class A Common Stock is above $11.50 per share.

You should carefully read this prospectus and any applicable prospectus supplement before you invest in our securities. The sale or the possibility of sale of the Class A Common Stock being offered pursuant to this prospectus may negatively impact the market price of the Class A Common Stock and Public Warrants.

The Class A Common Stock being offered for sale in this prospectus represents approximately 14.4% of our total outstanding Class A Common Stock on a fully diluted basis (assuming the issuance of all shares of Class A Common Stock issuable upon exercise of the Public Warrants and upon exchange of all outstanding Class C HoldCo Units and Class C Common Stock (each as defined herein)), as of the date of this prospectus. The sale of all the securities being offered in this prospectus could result in a significant decline in the public trading price of our Class A Common Stock. See “Risk Factors — Future resales of our Class A Common Stock may cause the market price of our Class A Common Stock to drop significantly, even if the Company’s business is doing well.”

Our Class A Common Stock and the Public Warrants are listed on Nasdaq under the symbols “ANNA” and “ANNAW”, respectively. On April 15, 2025, the last reported sales price of the Class A Common Stock was $12.57 per share, and the last reported sales price of our Public Warrants was $0.27 per Public Warrant. We are an “emerging growth company” and a “smaller reporting company” as defined under the U.S. federal securities laws and, as such, may elect to comply with certain reduced public company reporting requirements for this and future filings.

See “Risk Factors” beginning on page 9 to read about factors you should consider before investing in shares of our Class A Common Stock.

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or passed upon the accuracy or adequacy of this prospectus. Any representation to the contrary is a criminal offense.

The date of this prospectus is , 2025

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ABOUT THIS PROSPECTUS

This prospectus is part of a registration statement on Form S-1 that we filed with the Securities and Exchange Commission (the “SEC”). This prospectus relates to the issuance by us of shares of Class A Common Stock issuable upon the exercise of the Public Warrants.

We have not authorized anyone to provide you with any information or to make any representations other than those contained in this prospectus or any applicable prospectus supplement or any free writing prospectuses prepared by or on behalf of us or to which we have referred you. We do not take any responsibility for, or provide any assurance as to the reliability of, any other information that others may give you. We are not making an offer to sell these securities in any jurisdiction where the offer or sale is not permitted.

We may also provide a prospectus supplement or post-effective amendment to the registration statement to add information to, or update or change information contained in, this prospectus. You should read both this prospectus and any applicable prospectus supplement or post-effective amendment to the registration statement together with the additional information to which we refer you in the section of this prospectus titled “Where You Can Find Additional Information.”

THE BUSINESS COMBINATION

On December 13, 2024 (the “Closing Date”), AleAnna, Inc. (f/k/a Swiftmerge Acquisition Corp.) (“AleAnna”, the “Company” and, prior to the Closing Date, “Swiftmerge” or “SPAC”) consummated the previously announced business combination pursuant to that certain Agreement and Plan of Merger (as amended by that certain First Amendment to the Merger Agreement, dated as of October 8, 2024, the “Merger Agreement”), dated June 4, 2024, by and among Swiftmerge Acquisition Corp., a Cayman Islands exempted company (“Swiftmerge”), Swiftmerge HoldCo LLC, a Delaware limited liability company and wholly-owned subsidiary of Swiftmerge (“HoldCo”), Swiftmerge Merger Sub LLC, a Delaware limited liability company and wholly-owned subsidiary of HoldCo (“Merger Sub”) and AleAnna Energy, LLC, a Delaware limited liability company (“AleAnna Energy”, and such merger, the “Merger”). The transactions contemplated by the Merger Agreement are collectively referred to herein as the “Business Combination.”

Pursuant to the terms of the Merger Agreement, on December 13, 2024, the Company migrated to and domesticated as a Delaware corporation in accordance with Section 388 of the Delaware General Corporation Law, as amended, and the Companies Act (As Revised) of the Cayman Islands (the “Domestication”) and changed its name to AleAnna, Inc.

References to “Swiftmerge,” “SPAC,” “we,” “us,” or “our,” prior to the effective time of the Domestication refer to the Company when it was a Cayman Islands exempted company, and such references following the effective time of the Domestication and Merger refer to the Company in its current corporate form as a Delaware corporation called “AleAnna, Inc.” or “AleAnna.”

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MARKET AND INDUSTRY DATA

This prospectus contains estimates, projections and other information concerning AleAnna’s industry, including market size and growth of the markets in which it participates, that are based on industry publications and reports and forecasts prepared by its management. In some cases, AleAnna does not expressly refer to the sources from which these estimates and information are derived. While we are not aware of any misstatements regarding the market, industry or other data presented herein, such projections, assumptions and estimates of the future performance of the industry in which AleAnna operates and AleAnna’s future performance are necessarily subject to a high degree of uncertainty and risk due to a variety of factors, including those described in the section titled “Risk Factors.” These and other factors could cause results to differ materially from those expressed in these publications and reports.

Certain estimates of market opportunity, including internal estimates of the addressable market for AleAnna and forecasts of market growth, included in this prospectus may prove inaccurate. Market opportunity estimates and growth forecasts, whether obtained from third-party sources or developed internally, are subject to significant uncertainty and are based on assumptions and estimates that may prove to be inaccurate. The estimates and forecasts in this prospectus relating to the size of AleAnna’s target market, market demand and adoption, capacity to address this demand, and pricing may prove to be inaccurate. The addressable market AleAnna estimates may not materialize for many years, if ever, and even if the markets in which it competes meet the size estimates in this prospectus, AleAnna’s business could fail to successfully address or compete in such markets, if at all.

Certain monetary amounts, percentages and other figures included in this prospectus have been subject to rounding adjustments. Certain other amounts that appear in this prospectus may not sum due to rounding.

TRADEMARKS, SERVICE MARKS AND TRADE NAMES

This document contains references to trademarks and service marks belonging to other entities. Solely for convenience, trademarks and trade names referred to in this Registration Statement may appear without the ® or ™ symbols, but such references are not intended to indicate, in any way, that the applicable licensor will not assert, to the fullest extent under applicable law, its rights to these trademarks and trade names. We do not intend our use or display of other companies’ trade names, trademarks or service marks to imply a relationship with, or endorsement or sponsorship of us by, any other companies.

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CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

This prospectus contains forward-looking statements that involve substantial risks and uncertainties within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended, and Section 27A of the Securities Act of 1933, as amended. All statements other than statements of historical facts contained in this prospectus, including statements regarding the Company’s future financial position, business strategy and plans and objectives of management for future operations, are forward-looking statements. In some cases, you can identify forward-looking statements by terminology such as “may,” “will,” “should,” “expects,” “plans,” “anticipates,” “could,” “intends,” “targets,” “projects,” “contemplates,” “believes,” “estimates,” “predicts,” “potential” or “continue” or the negative of these terms or other similar expressions. Forward-looking statements include, without limitation, the Company’s expectations concerning the outlook for its business, market size, exploration and development plans, regulatory matters, competition and competitive position, operational performance, developments in the capital markets and expected future financial performance, as well as any information concerning possible or assumed future results of operations of the Company as set forth in the sections of this prospectus titled “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” and “Business.”

Forward-looking statements involve a number of risks, uncertainties and assumptions, and actual results or events may differ materially from those projected or implied in those statements. Important factors that could cause such differences include, but are not limited to:

• the Company’s financial condition and results of operations;

• the development of our estimated proved undeveloped reserves;

• the Company’s reserves estimates;

• the timing of acquisition, financing, construction and development of new projects;

• the Company’s ability to raise financing in the future;

• changes in public acceptance and support of renewable energy development and projects;

• the Company’s ability to obtain necessary regulatory and governmental permits and approvals;

• the effects of competition;

• the Company’s ability to identify, acquire, develop and operate renewable natural gas facilities;

• governmental incentives for renewable energy generation;

• the demand for renewable energy not being sustained;

• political, economic and other uncertainties, including those related to the European Union’s (“EU”) clean energy transition;

• changes in environmental laws and regulations; and

• the other matters described in the section titled “Risk Factors” beginning on page 9.

Forward-looking statements set forth herein are based on information currently available as of the date a forward-looking statement is made and speak only as of the date of this prospectus. The Company does not undertake any obligation to revise forward-looking statements to reflect future events, changes in circumstances, or changes in beliefs. In the event that any forward-looking statement is updated, no inference should be made that the Company will make additional updates with respect to that statement, related matters, or any other forward-looking statements. Any corrections or revisions and other important assumptions and factors that could cause actual results to differ materially from forward-looking statements, including discussions of significant risk factors, may appear in the Company’s public filings with the SEC, which are or will be (as appropriate) accessible at www.sec.gov, and which you are advised to consult. For additional information, please see the section titled “Where You Can Find More Information” on page 106.

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Market and industry data used throughout this prospectus, including statements regarding market size, is based on independent industry surveys and publications. These data involve a number of assumptions and limitations, and you are cautioned not to give undue weight to such estimates. While the Company is not aware of any misstatements regarding the industry data presented herein, its estimates involve risks and uncertainties and are subject to change based on various factors, including those discussed under the headings “Risk Factors” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in this prospectus.

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GLOSSARY OF SELECTED INDUSTRY TERMS

“Carbon Negative Renewable Natural Gas” |  | Renewable natural gas (RNG) is considered carbon negative if it captures more greenhouse gases than it emits. RNG produced from organic waste that would otherwise decay and create methane emissions are considered carbon negative as the methane emissions from the decay is captured and converted to a usable fuel source (RNG) which then displaces traditional fossil based natural gas (methane). The avoided emissions from natural decay and the substitution of fossil based natural gas results in a negative carbon life cycle score. In the U.S., the California Air Resources Board has given dairy and agricultural based carbon negative RNG projects a carbon intensity Score (gCO2e/MJ) of -250 (or lower). Such projects are similar to those pursued by AleAnna’s Renewable Natural Gas business.
“Development” |  | drilling and other post-exploration activities aimed at the production of oil and gas.
“Development well” |  | a well drilled within the proved area of an oil or gas reservoir to the depth of a stratigraphic horizon known to be productive.
“ESG” |  | environmental, social and governance.
“Exploration” |  | oil and natural gas exploration that includes land surveys, geological and geophysical studies, seismic data gathering and analysis and well drilling.
“Exploratory well” |  | a well drilled to find a new field or new reservoir in a field previously found to be productive of oil or gas in another reservoir. Generally, an exploratory well is any well that is not a development well, an extension well, a service well or a stratigraphic test well.
“Extension well” |  | a well drilled to extend the limits of a known reservoir.
“Gas” |  | all references to “gas” in this prospectus refer to natural gas.
“Greenhouse gases (GHG)” |  | gases in the atmosphere, transparent to solar radiation, that trap infrared radiation emitted by the earth’s surface. The greenhouse gases relevant within the Company’s activities are carbon dioxide (CO2), methane (CH4) and nitrous oxide (N2O). GHG emissions are commonly reported in CO2 equivalent (CO2eq) according to Global Warming Potential values in line with IPCC AR4, 4th Assessment Report.
“Gross” |  | “gross” natural gas and oil wells or “gross” acres equal the total number of wells or acres in which we have a working interest.
“G&A” |  | general and administrative.
“Hedging” |  | the use of derivative commodity and interest rate instruments to reduce financial exposure to commodity price and interest rate volatility.
“Hydrocarbons” |  | means oil, gas, condensate and other gaseous and liquid hydrocarbons or any combination thereof, and all minerals, products and substances extracted, separated, processed and produced therefrom or therewith.

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“LNG” |  | Liquefied Natural Gas obtained through the cooling of natural gas to minus 160 °C at normal pressure. The gas is liquefied to allow transportation from the place of extraction to the sites at which it is transformed back into its natural gaseous state and consumed. One tonne of LNG corresponds to 1,400 cubic meters of gas.
“Mcf” |  | thousand cubic feet.
“MMcf” |  | million cubic feet.
“Net” |  | “net” natural gas and oil wells or “net” acres equals the sum of our fractional ownership working interests we have in gross wells or acres.
“Net acres or Net wells” |  | the sum of the fractional working interest owned in gross acres or gross wells expressed in whole numbers and fractions of whole numbers.
“Possible reserves” |  | possible reserves are those additional reserves that are less certain to be recovered than probable reserves.
“Probable reserves” |  | probable reserves are those additional reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered.
“Productive well” |  | a well that is producing oil or gas or that is capable of production.
“Proved developed reserves” |  | proved reserves that can be expected to be recovered through existing wells with existing equipment and operating methods.
“Proved reserves” |  | proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible, from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations, prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time. Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions. Reserves are classified as either developed or undeveloped. Proved developed oil and gas reserves are reserves that can be expected to be recovered through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well, and through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the extraction is by means not involving a well. Proved undeveloped oil and gas reserves are reserves of any category that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion.

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“Proved undeveloped reserves (PUDs)” |  | means proved reserves that are expected to be recovered from undrilled well locations on existing acreage or from existing wells where a relatively major expenditure is required for recompletion within the five year development window, according to the SEC or Society of Petroleum Engineers definition of PUD
“Reserves” |  | reserves are estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. In addition, there must exist, or there must be a reasonable expectation that there will exist, the produce or a revenue interest in the production, installed means of delivering oil and gas or related substances to market, and all permits and financing required to implement the project.
“Reservoir” |  | a porous and permeable underground formation containing a natural accumulation of producible natural gas and/or oil that is confined by impermeable rock or water barriers and is separate from other reservoirs.
“Service well” |  | well drilled or completed for the purpose of supporting production in an existing field. Specific purposes of service wells include, among other things, gas injection, water injection and salt-water disposal.
“Undeveloped acreage” |  | means acreage under lease on which wells have not been drilled or completed such that there is not production of commercial quantities of hydrocarbons;
“Unproved reserves” |  | reserves that are based on geoscience and/or engineering data similar to that used in estimates of proved reserves, but technical or other uncertainties preclude such reserves being classified as proved reserves. Unproved reserves may be further categorized as probable reserves and possible reserves.
“Working interest” |  | An interest that gives the owner the right to drill, produce and conduct operating activities on a property and receive a share of any production.
“/d” |  | Per day.
“/y” |  | Per year.
“106ft3” |  | Millions of cubic feet.

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PROSPECTUS SUMMARY

Overview

AleAnna is a development-stage natural gas resource company focused on delivering critical natural gas supplies to Europe through both onshore conventional natural gas exploration and development and renewable natural gas development in Italy. As a development-stage company, AleAnna has not generated any revenue from its principal business activities other than from sales of electricity from two renewable gas assets that were purchased in July 2024. AleAnna is headquartered in Dallas, Texas, and has offices in Rome, Italy. Bluescape Resources Company LLC (“Bluescape”) is the majority investor in AleAnna through a series of wholly-owned entities including Nautilus Resources LLC (“Nautilus”), which beneficially owns approximately 84.85% of AleAnna’s voting power. The mailing address of AleAnna’s principal executive office is 300 Crescent Court, Suite 1860, Dallas, TX 75201, and its telephone number is (469) 398-2200.

Business Combination

On the Closing Date, AleAnna consummated the previously announced Business Combination pursuant to the Merger Agreement. Immediately prior to the closing of the Business Combination (the “Closing”), on December 13, 2024, as contemplated by the Merger Agreement, Swiftmerge became a Delaware corporation, upon which (i) Swiftmerge changed its name to “AleAnna, Inc.”; (ii) each Class A ordinary share, par value $0.0001 per share, of Swiftmerge (“Swiftmerge Class A Ordinary Shares”) converted into one share of Class A Common Stock; (iii) each Class B ordinary share, par value $0.0001 per share, of Swiftmerge (“Swiftmerge Class B Ordinary Shares”) converted into one share of Class B common stock, par value $0.0001 per share, of AleAnna (“Class B Common Stock”); (iv) each warrant to purchase Swiftmerge Class A Ordinary Shares converted on a one-to-one basis into a warrant to acquire shares of Class A Common Stock on the same terms and conditions as the converted warrants; and (v) a series of Class C common stock, par value $0.0001 per share, of AleAnna (“Class C Common Stock”) was authorized, each share of which has voting rights equal to a share of Class A Common Stock but which have no entitlement to earnings or distributions of AleAnna.

Following the Domestication, on December 13, 2024, pursuant to the Merger Agreement, (i) AleAnna contributed to Swiftmerge HoldCo LLC, a Delaware limited liability company (“HoldCo”) (1) all of its assets (excluding its interests in HoldCo), including, for the avoidance of doubt, the available cash, and (2) a number of shares of Class C Common Stock equal to the number of Class C units of HoldCo (“Class C HoldCo Units”) designated to be issued to the equity holders of the AleAnna Energy, LLC (“AleAnna Energy”) (collectively, the “AleAnna Energy Members”), and (ii) HoldCo issued to AleAnna a number of Class A units of HoldCo, which equaled the number of shares of Class A Common Stock issued and outstanding immediately after the Closing (the transactions described in clauses (i) and (ii) above, collectively, the “Pre-Closing Contribution”).

Following the Pre-Closing Contribution, Merger Sub merged with and into AleAnna Energy (the “Merger”), with AleAnna Energy being the surviving company and a wholly-owned subsidiary of HoldCo.

The aggregate merger consideration issued to the AleAnna Energy Members immediately prior to the Closing was equal to 65,098,476 shares of a combination of (i) 39,104,076 shares of Class A Common Stock and (ii) 25,994,400 shares of Class C Common Stock (with one Class C HoldCo Unit to accompany each share of Class C Common Stock) (the “Merger Consideration”).

On the Closing Date, each membership unit of AleAnna Energy issued and outstanding immediately prior to the Merger was cancelled and converted into and become the right to receive a portion of the Merger Consideration based on such unit holder’s right to certain distributions upon a sale of AleAnna Energy in accordance with AleAnna Energy’s operating agreement, as more particularly set forth in the Merger Agreement.

Prior to the extraordinary general meeting of Swiftmerge shareholders to approve the Business Combination and other related matters, holders of 1,158,556 Swiftmerge Class A Ordinary Shares sold in Swiftmerge’s initial public offering properly exercised their right to have their shares redeemed for a pro rata portion of the trust account holding the proceeds from Swiftmerge’s initial public offering, calculated as of two business days prior to the Closing. As a result, on December 13, 2024, prior to the Domestication, Swiftmerge redeemed 1,158,556 Swiftmerge Class A Ordinary Shares for $11.39 per share (the “Public Share Redemptions”).

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As of the Closing Date, following the Public Share Redemptions, the forfeiture of 2,535,001 Swiftmerge Class A Ordinary Shares, 1,689,999 Swiftmerge Class B Ordinary Shares and 9,350,000 Swiftmerge Private Warrants by Swiftmerge Holdings, LP, a Delaware limited partnership (the “Sponsor”), certain qualified institutional buyers or institutional accredited investors and certain unaffiliated third-party investors, as applicable, and the consummation of the Merger, there were (i) 40,560,433 shares of Class A Common Stock issued and outstanding, (ii) 25,994,400 shares of Class C Common Stock issued and outstanding, and (iii) 11,250,000 Public Warrants to acquire 11,250,000 shares of Class A Common Stock outstanding following the Business Combination. The Class A Common Stock and Public Warrants commenced trading on Nasdaq under the symbols “ANNA” and “ANNAW,” respectively, on December 16, 2024.

AleAnna is organized in an “Up-C” structure and the only direct assets of AleAnna consist of equity interests in HoldCo, whose only direct assets consist of equity interests in AleAnna Energy. Our business is conducted through AleAnna Energy and is subsidiaries.

Recent Developments

First Production at Longanesi

On March 13, 2025, AleAnna achieved a key milestone with the first production from its five wells in the Longanesi field.

In connection with this milestone, AleAnna will be required to reserve $3.1 million related to the contingent consideration liability due to Enel (see Note 6). These funds will be classified as restricted cash in future balance sheets and may be used to satisfy the contingent consideration liability as payments become due.

Gas Sale Agreement

On October 29, 2024, we entered into a gas sale agreement (“GSA”) with Shell Energy Europe Limited (“SEEL”), whereby SEEL became the exclusive buyer of our share of the natural gas produced from the Longanesi field net of (i) any consumption and/or losses incurred in the transport, treatment and compression of gas before delivery; (ii) any volume to be allocated for regulated royalties auctions, if applicable; and (iii) any other volume contractually allocated to other parties before August 31, 2022. Future sales under the GSA are contingent upon the commencement of gas production.

Renewable Natural Gas Acquisitions

Between March 2024 and July 2024, we successfully completed three separate strategic acquisitions of renewable natural gas plant projects in Italy for an aggregate of approximately $9.5 million. The plants are fully permitted and are in various stages of the development lifecycle, with one greenfield plant (Campagnatico) that is a new development and two brownfield plants (Casalino and Campopiano) that are currently operational.

Capital Contributions

Between January 2024 and May 2024, we received an aggregate of $62.1 million in capital contributions from our members, resulting in the issuance of 62,100 Class 1 Preferred Units, to fund operating costs and capital expenditures and provide working capital to meet our liabilities and commitments as they become due for at least the upcoming 12 months. These capital contributions were the final capital contributions to AleAnna Energy before the Business Combination and that all equity of AleAnna Energy, including the Class 1 Preferred Units, were exchanged for Class A and Class C Common stock as part of the December 13, 2024. We are using these funds to fulfill Longanesi gas pipeline and plant activity obligations, as well as general and administrative expenses.

Blugas Settlement

On May 28, 2024, we reached a settlement agreement (the “Blugas Settlement Agreement”) with Blugas Infrastructure S.r.l. (“Blugas”) regarding the Blugas overriding royalty interest (“ORRI”) whereby Blugas was entitled to physical delivery of 20% of the first 350 million standard cubic meters (approximately 2,472 106ft3) produced from the Longanesi field. Under the terms of the Blugas Settlement Agreement, we paid Blugas approximately €5 million, plus an additional €1.1 million in applicable VAT. In exchange, we were released from any future liability related to the

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Blugas ORRI. As a result of the transactions contemplated by the Blugas Settlement Agreement, our 33.5% working interest (net revenue interest) in the Longanesi field, as established under the terms of the Unified Operating Agreement arrangement originally signed between ENI and Grove and dated September 26, 2009, is now unencumbered except for normal government royalties (10%). The Blugas Settlement Agreement was accounted for as an acquisition of the Blugas ORRI claim with a corresponding increase to the expected future cash flows from our reserves. Our year-end December 31, 2023 reserve quantities included the 20% of 350 million standard cubic meters (approximately 2,472 106ft3) allocable to the Blugas ORRI in our proved gas reserves. However, the required payments to Blugas associated with the sale of such quantities were reflected as cash outflows (costs) in our year-end December 31, 2023 reserve report as if such amounts were paid to Blugas. Following settlement, our year-end December 31, 2024 reserve quantities continue to include the 20% of 350 million standard cubic meters (approximately 2,472 106ft3), however, the previously required payments to Blugas associated with the sale of such quantities are no longer reflected as cash outflows (costs) as if such amounts were paid to Blugas. As the cash outflows (costs) are no longer reflected as if paid to Blugas, such amounts are reflected in our December 31, 2024 reserve report as allocable to our unencumbered 33.5% working interest.

Implications of Being an Emerging Growth Company and a Smaller Reporting Company

We qualify as an “emerging growth company” as defined in the Jumpstart Our Business Startups Act of 2012 (the “JOBS Act”). For so long as we remain an emerging growth company, we are permitted, and currently intend, to rely on the following provisions of the JOBS Act that contain exceptions from disclosure and other requirements that otherwise are applicable to public companies and file periodic reports with the SEC. These provisions include, but are not limited to:

• being permitted to present only two years of audited financial statements and selected financial data and only two years of related “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our periodic reports and registration statements, including this prospectus, subject to certain exceptions;

• not being required to comply with the auditor attestation requirements of Section 404(b) of the Sarbanes-Oxley Act of 2002 (the “Sarbanes-Oxley Act”), as amended;

• reduced disclosure obligations regarding executive compensation in our periodic reports, proxy statements, and registration statements, including in this prospectus;

• not being required to comply with any requirement that may be adopted by the Public Company Accounting Oversight Board regarding mandatory audit firm rotation or a supplement to the auditor’s report providing additional information about the audit and the financial statements; and

• exemptions from the requirements of holding a nonbinding advisory vote on executive compensation and stockholder approval of any golden parachute payments not previously approved.

We will remain an emerging growth company until the earliest to occur of:

• December 14, 2026, which is the fifth anniversary of the effectiveness of Swiftmerge’s registration statement on Form S-1;

• the last day of the fiscal year in which we have total annual gross revenue of at least $1.235 billion, adjusted yearly for inflation;

• the date on which we are deemed to be a “large accelerated filer,” as defined in the Securities Exchange Act of 1934, as amended (the “Exchange Act”); and

• the date on which we have issued more than $1 billion in non-convertible debt over a three-year period.

We have elected to take advantage of certain of the reduced disclosure obligations in this prospectus and may elect to take advantage of other reduced reporting requirements in our future filings with the SEC. As a result, the information that we provide to holders of our stockholders may be different than what you might receive from other public reporting companies in which you hold equity interests.

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We have elected to avail ourselves of the provision of the JOBS Act that permits emerging growth companies to take advantage of an extended transition period to comply with new or revised accounting standards applicable to public companies. As a result, we will not be subject to new or revised accounting standards at the same time as other public companies that are not emerging growth companies.

We are also a “smaller reporting company” as defined under the Exchange Act. We may continue to be a smaller reporting company even after we are no longer an emerging growth company. We may take advantage of certain of the scaled disclosures available to smaller reporting companies until the fiscal year following the determination that (a) our voting and non-voting common stock held by non-affiliates is $250 million or more measured on the last business day of our second fiscal quarter, or (b) (1) our annual revenues are $100 million or more for the most recently completed fiscal year and (2) our voting and non-voting common stock held by non-affiliates is $700 million or more measured on the last business day of our second fiscal quarter.

Summary of Risk Factors

The risk factors summarized below could materially harm our business, operating results and/or financial condition, impair our future prospects and/or cause the price of our ordinary shares to decline. These risks are discussed more fully following this summary. Material risks that may affect our business, operating results and financial condition include, but are not necessarily limited to, the following:

Risks Related to our Conventional Natural Gas Business and the Conventional Natural Gas Industry

• We currently have no producing properties and there is no assurance that we will be able to convert our exploration drilling to producing wells. If our assets are not commercially productive of natural gas, any funds spent on exploration and production may be lost.

• The development of our estimated proved undeveloped reserves (“PUDs”) may take longer and may require higher levels of capital expenditures than we currently anticipate.

• While we have drilled and tested certain exploration wells, we have no history of converting the exploration wells to producing natural gas wells and there can be no assurance that we will successfully establish natural gas operations or profitably produce natural gas.

• Restrictions on drilling activities intended to protect the environment and the ecosystem may adversely affect our ability to conduct drilling activities areas where we operate.

• Drilling for and producing natural gas is a high-risk and costly activity with many uncertainties, including the risk that drilling will not result in commercially viable natural gas production or that we will not recover all or any portion of our investment in drilled wells.

• Our drilling locations are scheduled out over many years, making them susceptible to uncertainties that could materially alter the occurrence or timing of when they are drilled, if at all.

• The amount and timing of actual future natural gas production is difficult to predict and may vary significantly from our estimates, which may reduce our earnings.

• Unless we replace our reserves, our reserves and production will naturally decline, which would adversely affect our business, financial condition and results of operations.

• Our proved reserves are estimates that are based on many assumptions that may prove to be inaccurate. Any significant change in these underlying assumptions will greatly affect the quantities and present value of our reserves.

• Our limited history, lack of revenue and limited liquidity makes it difficult to evaluate our business and prospects and may increase the risks associated with your investment.

• Significant capital investment is required to develop and conduct our operations and we intend to raise additional funds through debt financing for our planned operations and these funds may not be available when needed.

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Risks Related to our Renewable Natural Gas Business and the Renewable Natural Gas Industry

• Failure to protect our intellectual property, inability to enforce our intellectual property rights or loss of our intellectual property rights through costly litigation or administrative proceedings, could adversely affect our ability to compete and our business.

• Our strategic success and financial results depend on our ability to identify, acquire, develop and operate renewable natural gas facilities.

• Revenue from any plants we complete may be adversely affected if there is a decline in public acceptance or support of renewable energy, or regulatory agencies, local communities, or other third parties delay, prevent, or increase the cost of constructing and operating our facilities.

• A policy revision with respect to the Italian government sponsored renewable natural gas floor price and renewable natural gas capital expenditure reimbursements could have a material adverse effect on our long-term business prospects, financial condition and results of operations.

• The financial performance of our business depends upon tax and other governmental incentives for renewable energy generation, any of which could change at any time and such changes may negatively impact our growth strategy.

• Our commercial success depends on our ability to develop and operate production facilities for the commercial production of renewable natural gas.

• We may be subject to liabilities and losses that may not be covered by insurance.

• Significant capital investment is required to develop and conduct our operations and we intend to raise additional funds through debt financing for our planned operations and these funds may not be available when needed.

• We have entered into relatively new markets for renewables, including renewable natural gas, and these new markets are highly volatile and have significant risk associated with current market conditions.

• Fluctuations in the price of product inputs, including renewable feedstocks, natural gas and other feedstocks, may affect our cost structure.

• Our proposed growth projects may not be completed or, if completed, may not perform as expected and our project development activities may consume a significant portion of our management’s focus, and if not successful, reduce our profitability.

• We may not be able to develop, maintain and grow strategic relationships, identify new strategic relationship opportunities, or form strategic relationships, in the future.

• Failure of third parties to manufacture quality products or provide reliable services in accordance with schedules, prices, quality and volumes that are acceptable to us could cause delays in developing and operating our commercial production facilities, which could damage our reputation, adversely affect our partner relationships or adversely affect our growth.

• We may be subject to liabilities and losses that may not be covered by insurance.

• Our facilities and processes may fail to produce renewable natural gas at the volumes, rates and costs we expect.

• Our actual costs may be greater than expected in developing our commercial production facilities or growth projects, causing us to realize significantly lower profits or greater losses.

• Disruption in the supply chain, including increases in costs, shortage of materials or other disruption of supply, or in the workforce could materially adversely affect our business.

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Risks Related to Foreign Operations and Regulatory Matters

• Our primary operations are in a foreign country and we are subject to political, economic and other uncertainties.

• All of our natural gas properties are located in the country of Italy, making us vulnerable to risks associated with operating in one geographic area.

• We may expand our operations globally, which would subject us to anti-corruption, anti-bribery, anti-money laundering, trade compliance, economic sanctions and similar laws, and non-compliance with such laws may subject us to criminal or civil liability and harm our business, financial condition and/or results of operations.

• Our results of operations, financial condition and cash flows could be adversely affected by changes in environmental laws and regulations.

Risks Related to our Organizational Structure, Class A Common Stock and Public Warrants

• AleAnna is a holding company and its organizational structure is commonly referred to as an umbrella partnership C corporation (or “Up-C”) structure, it is dependent upon distributions from HoldCo to pay taxes, and cover its corporate and other overhead expenses.

• Our management team has limited recent experience in operating a public company.

• We are controlled by Nautilus, whose interests may conflict with ours and the interests of other stockholders.

• If our estimates or judgments relating to our critical accounting policies prove to be incorrect or financial reporting standards or interpretations change, our operating results could be adversely affected.

• AleAnna Inc. has identified material weaknesses in its internal control over financial reporting. If we are unable to develop and maintain an effective system of internal control over financial reporting, we may not be able to accurately report our financial results in a timely manner, which may adversely affect investor confidence in us and materially and adversely affect our business and operating results, and we may face litigation as a result.

• The market price of our Class A Common Stock could be adversely affected by sales of substantial amounts of our Class A Common Stock in the public or private markets or the perception in the public markets that these sales may occur, including sales by the members of Nautilus after the redemption of any Class C HoldCo Units, together with an equal number of our Class C Common Stock, in exchange for shares of our Class A Common Stock, or other large holders.

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THE OFFERING

Shares of our Class A Common Stock outstanding prior to exercise of the Public Warrants |  | 40,560,433 shares
Shares of our Class A Common Stock that may be issued upon exercise of the Public Warrants |  | 11,225,969 shares
Shares of our Class A Common Stock outstanding after the exercise of the Public Warrants (excluding shares of Class A Common Stock issuable upon exchange of Class C HoldCo Units and Class C Common Stock) |  | 51,810,433 shares
Use of Proceeds |  | We will receive up to an aggregate of approximately $129.1 million, assuming the exercise in full of all of the Public Warrants for cash. As of April 16, 2025, we have received an aggregate of approximately $276,356.50 in cash proceeds upon exercise of Public Warrants. The likelihood that warrant holders will exercise the Public Warrants and any cash proceeds that we would receive is dependent upon the market price of our Class A Common Stock. If the market price for our Class A Common Stock is less than $11.50 per share, we believe holders of Public Warrants will be unlikely to exercise their Public Warrants. Under certain circumstances, the Public Warrants may be exercised on a cashless basis. If the Public Warrants are exercised on a cashless basis, we will not receive any cash from these exercises. Unless we inform you otherwise, we expect to use any net proceeds from the exercise of the Public Warrants for general corporate purposes. See the section titled “Use of Proceeds” for more information.
HoldCo Holder Redemption Right |  | Pursuant to the A&R HoldCo LLC Agreement, holders of Class C HoldCo Units and Class C Common Stock, subject to certain timing procedures and other conditions set forth therein, have the right (the “HoldCo Holder Redemption Right”) to exchange all or a portion of their Class C HoldCo Units, together with an equal number of shares of Class C Common Stock for shares of Class A Common Stock at an exchange ratio of one share of Class A Common Stock for each Class C HoldCo Unit exchanged, subject to conversion rate adjustments for stock splits, stock dividends and reclassifications and other similar transactions.

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Mandatory Exchange |  | The Company, in its capacity as manager of HoldCo, has the right to require, (i) upon a change of control of HoldCo or (ii) in the discretion of the Company with the consent of at least fifty percent (50%) of the holders of Class C HoldCo Units, each other HoldCo unitholder to exchange all of its Class C HoldCo Units for shares of Class A Common Stock at an exchange ratio of one share of Class A Common Stock for each Class C HoldCo Unit exchanged, subject to conversion rate adjustments for stock splits, stock dividends and reclassifications and other similar transactions (a “Mandatory Exchange”). In connection with any exchange of Class C HoldCo Units pursuant to the HoldCo Holder Redemption Right or acquisition of Class C HoldCo Units pursuant to a Mandatory Exchange, the Company shall receive a number of Class A HoldCo Units equal to the number of shares of Class A Common Stock issued to the HoldCo unitholder, and a corresponding number of shares of Class C Common Stock held by the relevant HoldCo unitholder will be cancelled. As the Class C HoldCo Units are exchanged, holding other assumptions constant, the Company’s ownership stake in HoldCo will be correspondingly increased, the number of shares of Class A Common Stock outstanding will be increased and the number of shares of Common Stock will be decreased.
Risk Factors |  | See the section titled “Risk Factors” and other information included in this prospectus for a discussion of factors that you should consider carefully before deciding to invest in our Class A Common Stock.
Ticker Symbol of Class A Common Stock and Public Warrants |  | “ANNA” and “ANNAW”

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RISK FACTORS

Any investment in shares of our Class A Common Stock involves a high degree of risk. You should carefully consider all of the information contained in this prospectus and any subsequent prospectus supplement, including our financial statements and related notes thereto, before deciding whether to purchase shares of our Class A Common Stock. However, such risks and those discussed elsewhere in any subsequent prospectus supplement are not the only ones we face. Additional risks and uncertainties that we are unaware of, or that we currently believe are not material, may also become important factors that adversely affect us. If any of the risks described in any subsequent prospectus supplement or others not specified therein materialize, our business, financial condition and results of operations could be materially and adversely affected. In that case, you may lose all or part of your investment.

Risks Related to our Conventional Natural Gas Business and the Conventional Natural Gas Industry

We currently have few producing properties and there is no assurance that we will be able to convert our pending exploration drilling to producing wells. If our assets are not commercially productive of natural gas, any funds spent on exploration and production may be lost.

As of December 31, 2024, many of our properties were not connected to midstream transportation, nor had we engaged service providers or contractors necessary for the productive development of such assets. There is no assurance that we will be able to obtain the midstream transportation or services necessary at economic costs, if at all. We are dependent on establishing sufficient reserves for additional cash flow and a return of our investment. If our properties are not economic, all of the funds that we have invested, or will invest, will be lost.

The development of our estimated PUDs may take longer and may require higher levels of capital expenditures than we currently anticipate. Therefore, our estimated PUDs may not ultimately be developed or produced.

All of the reserves attributable to our properties are undeveloped. Development of proved undeveloped reserves may take longer and require higher levels of capital expenditures than we currently anticipate. Delays in the development of our reserves, increases in costs to drill and develop such reserves, or decreases in commodity prices will reduce the value of our estimated PUDs and future net revenues estimated for such reserves and may result in some projects becoming uneconomic. In addition, delays in the development of reserves could require us to reclassify our PUDs as unproved reserves.

While we have drilled and tested certain exploration and development wells, we have no history of converting the exploration and development wells to producing natural gas wells and there can be no assurance that we will successfully establish natural gas operations or profitably produce natural gas.

We have drilled and tested certain exploration and development wells, but as of December 31, 2024, we had not successfully converted an exploration well or development well to a producing natural gas well nor successfully produced hydrocarbons, or revenues from drilling operations. We achieved first production of five drilled and tested wells in the Longanesi field in March 2025, following the installation of the temporary processing facility. The permanent processing facility is expected to be constructed over the remainder of 2025 and early 2026 and commissioned in mid-2026. Natural gas exploration and production has a high degree of risk. The future development of a significant portion of our properties will require obtaining permits and may require additional financing. As a result, we are subject to all of the risks associated with establishing new drilling operations and business enterprises, including, among others:

• the need to obtain necessary environmental and other governmental approvals and permits, the timing and conditions of those approvals and permits, and litigation concerning those approvals and permits;

• the availability and cost of funds to finance the drilling and development of our properties;

• the timing and cost, which can be considerable, of the supporting infrastructure to our natural gas drilling and production operations;

• the ability to obtain midstream offtake capacity for our future natural gas production;

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• drainage resulting from the development of offsetting properties from other operators in the area;

• commodity prices and our ability to find suitable customers for our future production;

• inflation and potential increases in costs of labor, power, supplies, services and other support; and

• the availability and retention of executives overseeing our operations and of skilled labor and equipment to support our drilling operations.

There is no assurance that our drilling activities will result in the successful production of natural gas. Moreover, there is no assurance that even if we are able to successfully produce natural gas that such production would be economical for commercial production. Natural gas production is dependent upon a number of factors and significantly influenced by the technical skill of our operations personnel involved. The commercial viability of our possible future production is also dependent upon a number of factors which are beyond our control, including the quality of our natural gas, commodity prices, government policies and regulation, and environmental protection requirements. There is no certainty that the expenditures that have been made and may be made in the future by us related to the acquisition and development of our properties will result in commercially viable production and our past and future expenditures may be partially or entirely lost.

Since we are a development-stage company with limited operating history and minimal revenue generation related to the production of natural gas assets, investors have a very limited basis to evaluate our ability to operate profitably as an E&P business.

We are a development-stage company. As of December 31, 2024 and December 31, 2023, we have not generated any revenue from our operations other than from sales of electricity from two renewable gas assets that were purchased in July 2024. We face many of the risks commonly encountered by other new businesses, including the lack of an established operating history, need for additional capital and personnel, and competition. There is no assurance that our business will be successful or that we can ever operate profitably. We may not be able to effectively manage the demands required, such that we may be unable to implement our business plan or achieve profitability.

Restrictions on drilling activities intended to protect the environment and the ecosystem may adversely affect our ability to conduct drilling activities areas where we operate.

Natural gas operations in our operating areas may be adversely affected by restrictions on drilling activities designed to protect the environment and the ecosystem. Such restrictions could prohibit drilling in certain areas, require the implementation of expensive mitigation measures or could result in limitations on our exploration and production activities that could have a material adverse impact on our ability to develop and produce our reserves or find new reserves on our undeveloped lands and permits.

In 2015, the Italian government published the Law 208/2015 which prohibited research, prospection and exploitation in waters within a 12-mile limit of the Italian Peninsula. Rockhopper Italia S.p.A., Rockhopper Mediterranean Ltd, and Rockhopper Exploration Plc (collectively, “Rockhopper”), was subsequently denied an application for an offshore production concession which had been pending since 2008. Rockhopper filed a request for arbitration to the International Center for the Settlement of the Investment Disputes (ICSID) against Italian Republic for the latter’s alleged failure to fulfill the legislative and regulatory commitments made in relation to the investments in the Ombrina Mare oil and gas field located off the Italian coast in the Adriatic Sea (ICSID Case no. ARB/17/14). On August 23, 2022 Italy was ordered to pay compensation to Rockhopper for the breach of its obligations. The Italian Republic sought to annul the award, and the related proceeding is still pending at ICSID for the decision of the “ad hoc Committee”. The Italian Republic also filed a request to continue the stay of the enforcement of the award. On April 24, 2023 the “ad hoc Committee” issued a decision on the provisional stay of enforcement of the award, providing that the provisional stay of enforcement is set to be lifted once Rockhopper puts in place relevant escrow arrangements. Similarly, our failure to obtain necessary government authorizations or the enactment of a legislative ban on exploration and production could result in indirect expropriation of our investment and assets.

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Drilling for and producing natural gas is a high-risk and costly activity with many uncertainties. Our future financial position, cash flows and results of operations depend on the success of our development and acquisition activities, which are subject to numerous risks beyond our control, including the risk that drilling will not result in commercially viable natural gas production or that we will not recover all or any portion of our investment in drilled wells.

Many factors may curtail, delay or cancel our scheduled drilling projects, or the development schedule, including the following:

• delays imposed by or resulting from compliance with regulatory requirements, including limitations resulting from permitting, emission of greenhouse gases (“GHGs”), and other limitations and regulatory requirements;

• intervention by local or federal governments or a foreign sovereign, such as appropriation of assets or technology or imposition of a ban on exploration or production activities;

• shortages of or delays in obtaining equipment, rigs, materials or qualified personnel;

• supply chain disruptions or labor shortage impacts;

• equipment failures, accidents or other unexpected operational events;

• lack of available capacity on interconnecting transportation pipelines;

• adverse weather conditions, such as flooding, droughts, freeze-offs, landslides, blizzards and ice storms;

• exposure to acts of terrorism or military or other armed conflict or political instability in regions that affect our business or operations;

• issues related to compliance with environmental regulations;

• environmental hazards;

• declines in natural gas market prices;

• limited availability of financing at acceptable terms;

• ongoing litigation or adverse court rulings;

• public opposition to our operations;

• title, surface access, coal mining and right of way issues; and

• limitations in the market for natural gas.

In addition, we may become subject to additional laws or regulations issued by federal or state government bodies, which are subject to influence resulting from frequent changes in political party control or changes to political priorities or policies. We may need to adapt compliance strategies and operation to meet new regulatory requirements, which can be costly and time-consuming.

Any of these risks can cause a delay in our development program, or result in substantial financial losses, personal injury or loss of life, damage to or destruction of property, natural resources and equipment, pollution, environmental contamination or loss of wells and other regulatory penalties. Adjustments to our planned development schedule or the development schedule of non-operated wells in which we have a working interest could impact our future sales volume, operating revenues and expenses, per unit metrics and capital expenditures.

We are subject to risks associated with the operation of our wells.

Our business is and will be subject to all of the inherent hazards and risks normally incidental to drilling for, producing, transporting, storing, processing, gathering and compressing natural gas, such as fires, explosions, slips, landslides, blowouts, and well cratering; pipe and other equipment and system failures; delays imposed by, or resulting from, compliance with regulatory requirements; formations with abnormal or unexpected pressures; shortages of, or

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delays in, obtaining equipment and qualified personnel; adverse weather conditions, such as freeze offs of wells and pipelines due to cold weather; issues related to compliance with environmental regulations; environmental hazards, such as natural gas leaks, pipeline and tank ruptures, encountering naturally occurring radioactive materials, and unauthorized releases of toxic gases or other pollutants into the environment. We also may face various risks or threats in the future to the operation and security of our or third parties’ facilities and infrastructure, such as processing plants, compressor stations and pipelines. Any of these risks could result in substantial losses due to personal injury and/or loss of life, severe damage to and destruction of property, equipment and natural resources, pollution or other environmental damage, loss of hydrocarbons, disruptions to our operations, regulatory investigations and penalties, suspension of our operations, repair and remediation costs, and loss of sensitive confidential information. Moreover, in the event that one or more of these hazards occur, there can be no assurance that a response will be adequate to limit or reduce damage. Although we maintain property insurance, there can be no assurance that such coverage will be adequate or will cover any particular incident in the event of a catastrophe or significant disruption of our business, or that we will be able to obtain sufficient insurance coverage in the future.

We have limited control over the activities on properties we do not operate.

Presently Società Padana Energia (“Padana”) is the operator of the Longanesi field under a Unitized Operating Agreement and other companies in the future may operate some of the properties in which we have an interest. We may also enter into a future joint venture with respect to our properties. Except for mutually agreed governance provisions in the Unitized Operating Agreement, we have limited ability to influence or control the operation or future development of the Longanesi field and potential future non-operated properties including any properties that may be operated shared control joint ventures where we may share control with third parties, including compliance with environmental, safety and other regulations or the amount of capital expenditures that we are required to fund with respect to them. The failure of an operator of our wells or joint venture participant to adequately perform operations, an operator’s breach of the applicable agreements or an operator’s failure to act in ways that are in our best interest could reduce our production and revenues. Our dependence on the operator and other working interest owners, including a joint venture participant, for these projects and our limited ability to influence or control the operation and future development of these properties could materially adversely affect the realization of our targeted returns on capital in drilling or acquisition activities and lead to unexpected future costs.

Our drilling locations are scheduled out over many years, making them susceptible to uncertainties that could materially alter the occurrence or timing of when they are drilled, if at all.

Our management team has specifically identified and scheduled certain well locations as an estimation of our future multi-year drilling activities on our existing acreage. These well locations (prospects) represent a significant part of our business strategy. Our ability to drill and develop these locations depends on a number of uncertainties, including natural gas prices; the availability and cost of capital; drilling and production costs; the availability of drilling services and equipment; drilling results; topography; gathering system and pipeline transportation costs and constraints; regulatory approvals; and other factors. Because of these uncertain factors, we do not know if the drilling locations we have identified will ever be drilled or if we will be able to produce natural gas from these or any other drilling locations.

The amount and timing of actual future natural gas production is difficult to predict and may vary significantly from our estimates, which may reduce our earnings.

Because the rate of production from natural gas wells generally declines as reserves are depleted, our future success depends upon our ability to develop additional reserves that are economic and our failure to do so may reduce our earnings. Our drilling and subsequent maintenance of wells can involve significant risks, including those related to timing, cost overruns and operational efficiency, and these risks can be affected by the availability of capital, leases, rigs, equipment and a qualified work force, as well as weather conditions, natural gas price volatility, regulatory approvals, geology, equipment failure or accidents and other factors. Drilling for natural gas can be unprofitable, not only due to dry wells, but also as a result of productive wells that perform below expectations or that do not produce sufficient revenues to return a profit. Low natural gas prices may further limit the types of reserves that we can develop and produce economically.

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Except to the extent that we acquire additional properties containing proved reserves, conduct successful exploration and development activities or otherwise, our proved reserves will decline as reserves are produced. Our future natural gas production, therefore, is highly dependent upon our level of success in acquiring or finding additional reserves that are economically recoverable. We cannot be certain that we will be able to find or acquire and develop additional reserves at an acceptable cost. Without continued successful development or acquisition activities, together with efficient operation of existing wells, our reserves and production, together with associated revenues, will decline as a result of our current reserves being depleted by production.

Unless we replace our reserves, our reserves and production will naturally decline, which would adversely affect our business, financial condition and results of operations.

Unless we conduct successful development or acquire properties containing proved reserves, our proved reserves will decline as those reserves are produced. Producing natural gas reservoirs generally are characterized by declining production rates that vary depending upon reservoir characteristics and other factors. Our natural gas reserves and production, and therefore our cash flows and income, are highly dependent on our success in efficiently developing our current reserves and economically finding or acquiring additional recoverable reserves. We may not be able to develop, find or acquire additional reserves to replace our current and future production at acceptable costs. If we are unable to replace our current and future production, the value of our reserves will decrease, and our business, financial condition and results of operations will be adversely affected.

Our proved reserves are estimates that are based on many assumptions that may prove to be inaccurate. Any significant change in these underlying assumptions will greatly affect the quantities and present value of our reserves.

Reserve engineering is a subjective process involving estimates of underground accumulations of natural gas and assumptions concerning future prices, production levels and operating and development costs, some of which are beyond our control. These estimates and assumptions are inherently imprecise, and we may adjust our estimates of proved reserves based on changes in these estimates or assumptions. As a result, estimated quantities of proved reserves and projections of future production rates and the timing of development expenditures may prove to be inaccurate. Any significant variance from our assumptions could greatly affect our estimates of reserves, the economically recoverable quantities of natural gas, the classifications of reserves based on risk of recovery and estimates of future net cash flows. To the extent we experience a sustained period of reduced commodity prices, there is a risk that a portion of our proved reserves could be deemed uneconomic and no longer be classified as proved. Although we believe our estimates are reasonable, actual production, revenues and costs to develop reserves will likely vary from our estimates and these variances could be material. Numerous changes over time to the assumptions on which our reserve estimates are based, as described above, often result in the actual quantities of natural gas we ultimately recover being different from our reserve estimates.

The standardized measure of discounted future net cash flows from our proved reserves is not the same as the current market value of our estimated natural gas reserves.

You should not assume that the standardized measure of discounted future net cash flows from our proved reserves is the current market value of our estimated natural gas reserves. In accordance with SEC requirements, we based the discounted future net cash flows from our proved reserves on the twelve-month unweighted arithmetic average of the first-day-of-the-month price for the preceding 12 months without giving effect to derivative transactions. Actual future net cash flows from our reserves will be affected by factors such as the actual prices we receive for natural gas, the amount, timing and cost of actual production and changes in governmental regulations or taxation. The timing of both our production and our incurrence of expenses in connection with the development and production of natural gas properties will affect the timing and amount of actual future net revenues from proved reserves, and thus their actual present value. In addition, the 10% discount factor we use when calculating the standardized measure may not be the most appropriate discount factor based on interest rates in effect from time to time and risks associated with our operations or the natural gas industry in general.

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Natural gas prices are affected by a number of factors beyond our control, including many of which that are unknown and cannot be anticipated, and we cannot predict with certainty future potential movements in the price for these commodities.

Our primary business involves the exploration, production and sale of natural gas. Consequently, our revenue, profitability, future rate of growth, liquidity and financial position depend upon the market prices for natural gas in Italy.

The prices for natural gas in Italy have historically been volatile and have been particularly volatile in recent years. We expect commodity price volatility to continue or increase in the future due to rising macroeconomic uncertainty and geopolitical tensions.

Commodity prices are affected by a number of factors beyond our control, which include:

• weather conditions and seasonal trends;

• global and regional supply of and demand for natural gas;

• regulatory constraints on pricing, prevailing prices in the areas in which we operate, and expectations about future commodity prices;

• new or continuing armed conflicts or hostilities, or acts of terrorism;

• national and worldwide economic and political conditions, particularly those in, or affecting, other countries which are significant producers of natural gas;

• new and competing exploratory finds of natural gas;

• changes in exports of natural gas producing countries, such as the United States and Russia;

• the effect of energy conservation efforts;

• the price, availability and consumer demand for alternative fuels;

• the availability, proximity, capacity and cost of pipelines, other transportation facilities, and gathering, processing and storage facilities and other factors that result in differentials to benchmark prices;

• technological advances affecting energy consumption and production;

• the actions of the Organization of Petroleum Exporting Countries;

• the level and effect of trading in commodity futures markets, including commodity price speculators and others;

• the cost of exploring for, developing, producing and transporting natural gas;

• risks associated with drilling, completion and production operations; and

• governmental regulations, tariffs and taxes, including environmental and climate change regulation.

A prolonged period of low natural gas prices may have an adverse effect on our revenue, profitability, future rate of growth, liquidity and financial position.

Prolonged low, and/or significant or extended declines in, natural gas prices may adversely affect our revenues, operating income, cash flows, financial projections, and financial position, particularly if we are unable to control our development costs during periods of lower natural gas prices. Declines in prices could also adversely affect our drilling activities and the amount of natural gas that we can produce economically, which may result in our having to make significant downward adjustments to the value of our assets and could cause us to incur non-cash impairment charges to earnings. Reductions in cash flows from lower commodity prices may require us to incur debt or reduce our capital spending, which could reduce our production and our reserves, negatively affecting our future rate of growth.

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A financial crisis or deterioration in general economic, business or geopolitical conditions could materially adversely affect our operations and financial condition.

Concerns over global economic conditions, stock market volatility, energy costs, geopolitical issues (including continued hostilities between Russia and Ukraine as well as other conflicts, including in the Middle East), inflation and central bank interest rate increases in response thereto, the availability and cost of credit, and slowing of global economic growth and fears of a recession have contributed and may continue to contribute to increased economic uncertainty and diminished expectations for the global economy. Global economic conditions, geopolitical issues and inflation have constrained global and domestic supply chains, which may in the future impact our ability to develop our reserves in accordance with our drilling and completions schedule. Additionally, global economic conditions have a significant impact on commodity prices and any stagnation or deterioration in global economic conditions could result in decreased demand and, thus, lower prices for natural gas. Such uncertainty could also result in higher natural gas prices, which could potentially result in increased inflation worldwide and could negatively impact demand for natural gas.

Developments related to climate change may expedite a transition away from the use of carbon-intensive sources for energy generation and products derived from certain fossil fuels, which could have a material and adverse effect on us if we are not able to demonstrate that our products align with a low-carbon transition.

Governmental and regulatory bodies, investors, consumers, industry participants and other stakeholders have been increasingly focused on combating the effects of climate change. This focus, together with changes in consumer, industrial and commercial behavior, preferences and attitudes with respect to the generation and consumption of energy, and the use of products manufactured with, or powered by, fossil fuels, has led to, and in the long-term is anticipated to continue to result in, (i) the enactment of climate change-related regulations, policies and initiatives, (ii) technological advances with respect to the generation, transmission, storage and consumption of energy, and (iii) increased consumer, industrial and commercial demand for low-carbon energy sources and products manufactured with, or powered by, demonstrably low carbon-intensive sources. This has in turn led to increased scrutiny over the carbon-intensity of various fossil fuels, including the natural gas we intend to produce and sell. While the EU has identified natural gas as a critical bridging resource in its 2050 climate neutrality pledge, there is no guarantee that perspective will be maintained and if we are not able to demonstrate that our products align with a transition to a low-carbon economy, the demand and prices for our products could be negatively impacted depending on the pace of such transition and potential future demands for low-carbon products. Such developments may also adversely impact, among other things, the availability of third-party services and facilities that we rely on, which may increase our operational costs and adversely affect our ability to successfully carry out our business strategy. Climate change-related developments may also impact the market prices of, or our access to, raw materials such as energy and water and therefore result in increased costs to our business.

Further, there have been efforts in recent years to influence the investment community, including investment advisors, insurance companies, and certain sovereign wealth, pension and endowment funds and other groups, by promoting divestment of fossil fuel equities and pressuring lenders to limit funding and insurance underwriters to limit coverages to companies engaged in the extraction of fossil fuel reserves. Financial institutions may elect in the future to shift some or all of their investment into non-fossil fuel related sectors. There is also a risk that financial institutions may be required to adopt policies that have the effect of reducing the funding provided to the fossil fuel sector. Certain investment banks and asset managers based both domestically and internationally have announced that they are adopting climate change guidelines for their banking and investing activities. Institutional lenders who provide financing to energy companies have also become more attentive to sustainable lending practices, and some may elect not to provide traditional energy producers or companies that support such producers with funding. Ultimately, the foregoing factors could make it more difficult to secure funding for exploration and production activities or adversely impact the cost of capital for both us and our customers, and could thereby adversely affect the demand and price of our securities. Limitation of investments in and financings for energy companies could also result in the restriction, delay or cancellation of infrastructure projects and energy production activities.

Our operations have substantial capital requirements, and we may not be able to obtain needed capital or financing on satisfactory terms, or at all.

Our business is capital intensive. We make and expect to continue to make substantial capital expenditures for the development and acquisition of natural gas reserves, as well as related infrastructure. If these projects are undertaken, they may not be completed on schedule, at the budgeted cost or at all. To date, we have invested approximately

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$227 million in the acquisition and initial development of our properties. While we expect to be able to fund our future growth primarily out of cash currently on AleAnna’s balance sheet, from cash flow from the Longanesi, Trava, and Gradizza developments, and through recycling of cash flow from future developments, we have not generated any revenue from our principal business activities to date and do not have available commitments from debt financing sources. While we are exploring Resource Backed Loan (“RBL”) financing products with several financial institutions, there is no guarantee that such financing will be available to us. We believe that the cash currently on AleAnna’s balance sheet is sufficient, at a minimum, to cover general and administrative expenses and continue operating our revenue-producing assets through at least the end of the second quarter of 2026. Despite first production at Longanesi being achieved in March 2025 and having adequate cash on hand to cover general and administrative expenses and maintain operations, we may be required to curtail discretionary development efforts on Gradizza, Trava, renewable natural gas asset acquisitions, and other conventional prospects. Lower-than-expected cash flow from Longanesi or an interruption in operations of Longanesi, combined with delays in development of Gradizza, Trava, renewable natural gas asset acquisitions, and other conventional prospects may lead to a deteriorated financial condition, erode potential value due to delays in our discretionary developments, and adversely affect our results of operations.

The actual amount and timing of our future capital expenditures may differ materially from our estimates as a result of, among other things, natural gas prices, actual drilling results, the availability of drilling rigs and other services and equipment, and regulatory, technological and competitive developments.

Our cash flows from operations and access to capital are subject to a number of variables, including:

• our level of proved reserves and production;

• the level of hydrocarbons we are able to produce from existing wells;

• our access to, and the cost of accessing, end markets for our production;

• the prices at which our production is sold;

• our ability to acquire, locate and produce new reserves;

• the levels of our operating expenses; and

• our ability to access the public or private debt and equity capital and lending markets.

If we are unable to obtain the capital necessary for our planned capital budget or our operations, we could be required to curtail our operations and the development of our properties, which in turn could lead to a decline in our reserves and production, and could adversely affect our business, results of operations and financial position.

Derivative transactions may limit our potential gains and involve other risks.

To manage our exposure to price risk, we may in the future enter into derivative arrangements, utilizing commodity derivatives with respect to a portion of our future production. Such hedges are designed to lock in prices in order to limit volatility and increase the predictability of cash flow. These transactions may be required to the extent we utilize RBL financing in the future and such limit our potential gains if natural gas prices rise above the price established by the hedge, and we may be required to post cash collateral or letters of credit with our hedge counterparties to the extent our liability under the derivative contract exceeds specified thresholds, which would negatively impact our liquidity. Derivative transactions may expose us to the risk of financial loss in certain circumstances, including instances in which our production is less than expected or an event materially impacts natural gas prices or the relationship between the hedged price index and the natural gas sales price.

We cannot be certain that any derivative transaction we may enter into will adequately protect us from declines in the prices of natural gas. Furthermore, where we choose not to engage in derivative transactions in the future, we may be more adversely affected by changes in natural gas prices than our competitors who engage in derivative transactions. Lower natural gas prices may also negatively impact our ability to enter into derivative contracts at favorable prices.

Derivative transactions may also expose us to a risk of financial loss if a counterparty fails to perform under a derivative contract or enters bankruptcy or encounters some other similar proceeding or liquidity constraint. In this case, we may not be able to collect all or a significant portion of amounts owed to us by the distressed entity or entities. During periods of falling commodity prices our hedge receivable positions increase, which increases our exposure. If the creditworthiness of our counterparties deteriorates and results in their nonperformance, we could incur a significant loss.

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Our business and prospects depend significantly on our ability to build our brand and we may not succeed in continuing to establish, maintain, and strengthen our brand, and our brand and reputation could be harmed by negative publicity regarding our company.

Our business and prospects are dependent on our ability to develop, maintain, and strengthen our brand. Promoting and positioning our brand will depend significantly on our ability to execute our business strategies and build market relationships. In addition, we expect that our ability to develop, maintain, and strengthen our brand will also depend heavily on the success of our branding efforts. To promote our brand, we need to incur increased expenses, such as the costs associated with attending trade conferences. Brand promotion activities may not yield increased revenue, and even if they do, the increased revenue may not offset the expenses we incur in building and maintaining our brand and reputation. If we fail to promote and maintain our brand successfully, or if we incur substantial expenses in an unsuccessful attempt to promote and maintain our brand, we may fail to build a market presence and we may fail to be viewed as an attractive investment platform in which case our business and financial condition may be adversely affected.

We also believe that the protection of our trademark rights is an important factor in protecting our brand and maintaining goodwill. We may be unable to obtain trademark protection for our technologies, logos, slogans and brands, and our existing trademark registrations and applications, and any trademarks that may be used in the future, may not provide us with competitive advantages or distinguish us from those of our competitors. Further, we may not timely or successfully register our trademarks. If we do not adequately protect our rights in our trademarks from infringement and unauthorized use, any goodwill that we have developed in those trademarks could be lost or impaired, which could harm our brand and our business.

Moreover, any negative publicity relating to our employees, current or future partners, our technology, our natural gas, or customers who use our technology or natural gas, or others associated with these parties may also tarnish our own reputation simply by association and may reduce the value of our brand. Additionally, if safety or other incidents or defects in our natural gas pipeline occur or are perceived to have occurred, whether or not such incidents or defects are our fault, we could be subject to adverse publicity, which could be particularly harmful to our business given our limited operating history. Given the popularity of social media, any negative publicity about our products, whether true or not, could quickly proliferate and harm customer and community perceptions and confidence in our brand. Other businesses, including our competitors, may also be incentivized to fund negative campaigns against our company to damage our brand and reputation to further their own purposes. Future customers of our products and services may have similar sensitivities and may be subject to similar public opinion and perception risks. Damage to our brand and reputation may result in difficulty attracting and retaining investors, reduced demand for our products and increased risk of losing market share to our competitors. Any efforts to restore the value of our brand and rebuild our reputation may be costly and may not be successful, and our inability to develop and maintain a strong brand could have an adverse effect on our business, prospects, financial condition, and operating results.

Cyber incidents targeting our digital work environment or other technologies or energy infrastructure may adversely impact our operations.

The natural gas industry has become increasingly dependent upon digital technologies, including information systems, infrastructure and cloud applications, and the maintenance of our financial and other records has long been dependent upon such technologies. We may depend on this technology to record and store data, estimate quantities of natural gas reserves, analyze and share operating data and communicate internally and externally. Computers and mobile devices control nearly all of the natural gas distribution systems globally, which will be necessary to transport our products to market.

Energy assets might be specific targets of cyber or other security or physical threats, and the continuing armed conflict between Russia and Ukraine and associated economic sanctions on Russia may have increased the likelihood of such threats. We can provide no assurance that we will not suffer such attacks in the future. Deliberate attacks on, or unintentional events affecting, our digital work environment or other technologies and infrastructure, the systems or infrastructure of third parties or the cloud could lead to corruption or loss of our proprietary data and potentially sensitive data, delays in production or delivery of natural gas, difficulty in completing and settling transactions, challenges in maintaining our books and records, communication interruptions, environmental damage, personal injury, property damage, other operational disruptions and third-party liability. Further, as cyber incidents continue to evolve and cyber attackers become more sophisticated, we may be required to expend additional resources to continue to modify or enhance our protective measures or to investigate and remediate any vulnerability to cyber incidents.

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The cost to remedy an unintended dissemination of sensitive information or data may be significant. Furthermore, the continuing and evolving threat of cyber-attacks has resulted in increased regulatory focus on prevention. To the extent we face increased regulatory requirements, we may be required to expend significant additional resources to meet such requirements.

The unavailability or high cost of additional drilling rigs, completion services, equipment, supplies, personnel, and oilfield services could adversely affect our ability to execute our exploration and development plans within our budget and on a timely basis.

The demand for qualified and experienced field personnel to drill wells and conduct field operations, geologists, geophysicists, engineers, and other professionals in the natural gas industry can fluctuate significantly, often in correlation with natural gas and oil prices, causing periodic shortages or higher costs. We cannot predict whether these conditions will exist in the future and, if so, what their timing and duration will be. Such shortages could delay or cause us to incur significant expenditures that are not provided for in our capital budget, which could materially adversely affect our business, results of operations, cash flows and financial position.

The loss of key personnel could adversely affect our ability to execute our strategic, operational and financial plans.

Our operations are dependent upon key management and technical personnel, and one or more of these individuals could leave our employment. The unexpected loss of the services of one or more of these individuals could have a detrimental effect on us. In addition, the success of our operations will depend, in part, on our ability to identify, attract, develop and retain experienced personnel. There is competition within our industry for experienced technical personnel and certain other professionals, which could increase the costs associated with identifying, attracting and retaining such personnel. If we cannot identify, attract, develop and retain our technical and professional personnel or attract additional experienced technical and professional personnel, our ability to compete in our industry could be harmed.

We will depend on state-owned midstream providers for midstream services, and our failure to obtain and maintain access to the necessary infrastructure to successfully deliver natural gas to market on acceptable terms may adversely affect our earnings, cash flows and results of operations.

Our delivery of natural gas depends upon the availability, proximity and capacity of pipelines, other transportation facilities and gathering and facilities that are state-owned. To the extent these services are delayed or unavailable, we would be unable to realize revenue from wells served by such state-owned infrastructure until suitable arrangements are made to market our production. Access to midstream assets may be unavailable due to market conditions, regulatory constraints or mechanical or other reasons. Further, changes in the Italian Transmission Operator’s Network may have an adverse effect on us. In addition, due to regulatory and economic constraints, construction of new pipelines and building of such infrastructure may occur more slowly. A lack of access to needed infrastructure, or an extended interruption of access to or service from state-owned pipelines and facilities for any reason, including vandalism, terroristic acts, sabotage or cyber-attacks on such pipelines and facilities or service interruptions due to gas quality, could result in adverse consequences to us, such as delays in producing and selling our natural gas.

Unexpected increases in fees related to transportation facilities and providers may negatively impact our financial position or projections.

A significant increase in transportation fees and fuel prices may adversely affect our transportation costs and business. Transportation providers (rail and truck) in some circumstances have limited ability to provide additional resources in times of peak demand. Moreover, the ability of our transportation providers to maintain a staff of qualified personnel is critical to the success of our business. Regulatory requirements and an improvement in the economy could require us to pay higher transportation fees as our transportation providers seek to pass on additional labor costs associated with attracting and retaining personnel.

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Risks Related to our Renewable Natural Gas Business and the Renewable Natural Gas Industry

Failure to protect our intellectual property, inability to enforce our intellectual property rights or loss of our intellectual property rights through costly litigation or administrative proceedings, could adversely affect our ability to compete and our business.

Our success depends in large part on our ability to protect proprietary intellectual property rights for commercially important trade secrets and know-how related to our business including our proprietary seismic imaging and interpretation techniques and our renewable natural gas acquisition pipeline and our ability to defend and enforce intellectual property rights and preserve confidentiality. We must also operate without infringing, misappropriating, or violating the valid and enforceable patents and other intellectual property rights of third parties. We rely on various intellectual property rights, including trade secrets, as well as confidentiality provisions and contractual arrangements, and other forms of statutory protection to protect our proprietary rights. We will be able to protect our proprietary rights from unauthorized use by third parties only to the extent that our proprietary trade secrets, know-how, and technologies are covered by valid and enforceable patents or are effectively maintained as trade secrets. If we do not protect and enforce our intellectual property rights adequately and successfully, our competitive position may suffer, which could have a material adverse effect on our business, prospects, financial condition, and operating results.

Our strategic success and financial results depend on our ability to identify, acquire, develop and operate renewable natural gas plants.

Our renewable natural gas business strategy includes growth primarily through the acquisition and expansion of existing renewable natural gas plants. In particular, we intend to develop and grow our renewable natural gas business through the acquisition of operational anaerobic digesters and their conversion to biomethane plants. This strategy depends on our ability to successfully identify and evaluate acquisition opportunities and complete acquisitions on favorable terms. However, we cannot assure you that we will be able to successfully identify new opportunities or consummate the acquisition of existing renewable natural gas plants, on favorable terms or at all. In addition, we will compete with other companies and private equity sponsors for these opportunities, which may increase our costs or cause us to refrain from making acquisitions at all. If we are unable to successfully identify and consummate future project opportunities or acquisitions of existing plants it will impede our ability to execute our growth strategy.

Our ability to acquire, develop and operate renewable natural gas plants, is subject to various risks, including:

• regulatory changes that affect the value of renewable natural gas, including revisions to government sponsored price floors and any potential inability to qualify or potential disqualification from such programs, which could have a significant effect on the financial performance of the number of potential plants with attractive economics;

• changes in energy commodity prices, such as natural gas and wholesale electricity prices, which could have a significant effect on our revenues and expenses;

• changes in pipeline gas quality standards or other regulatory changes that may limit our ability to transport renewable natural gas on pipelines for delivery to third parties or increase the costs of processing renewable natural gas to allow for such deliveries;

• changes in the broader waste collection industry, including changes affecting the waste collection and biogas potential of the farming industry, which could limit the renewable natural gas resource that we currently target for our plants;

• substantial construction risks, including the risk of delay, that may arise due to forces outside of our control, including those related to engineering and environmental problems, inclement weather and labor disruptions;

• In order to construct new commercial and modify existing production facilities, we typically face a potentially lengthy and variable design, fabrication, and construction development cycle that requires resource commitments and may create fluctuations in whether and when revenue is recognized;

• operating risks and the effect of disruptions on our business, including the effects of weather conditions, catastrophic events such as fires, explosions, earthquakes, droughts and acts of terrorism, and other force majeure events on us, our customers, suppliers, distributors and subcontractors;

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• accidents involving personal injury or the loss of life, as a result of work conditions including, but not limited to, hazardous worksite site conditions and gas exposure;

• the ability to obtain financing for a project on acceptable terms or at all and the need for substantially more capital than initially budgeted to complete plants and exposure to liabilities as a result of unforeseen environmental, construction, technological or other complications;

• failures or delays in obtaining desired or necessary land rights, including ownership, leases, easements, zoning rights and building permits;

• a decrease in the availability, pricing and timeliness of delivery of raw materials and components necessary for the operation of plants;

• obtaining and keeping in good standing permits, authorizations and consents from governmental organizations;

• unknown regulatory changes for renewable natural gas which may increase the transportation cost for delivering under contracts in place;

• the consent and authorization of local utilities or other energy development off-takers to ensure successful interconnection to energy grids to enable power and gas sales; and

• difficulties in identifying, obtaining and permitting suitable sites for new plants.

Any of these factors could prevent us from acquiring, developing, or operating plants, or otherwise adversely affect our business, financial condition and results of operations.

Acquiring existing plants involves numerous risks.

The acquisition of existing renewable natural gas plants involves numerous risks, many of which may be indiscoverable through the due diligence process, including exposure to previously existing liabilities and unanticipated costs associated with the pre-acquisition period; difficulty in integrating the acquired plants into our existing business; and, if the plants are in new markets, the risks of entering markets where we have limited experience, less knowledge of differences in market terms for gas rights agreements and off-take arrangements. While we perform due diligence on prospective acquisitions, we may not be able to discover all potential operational deficiencies in such plants. A failure to achieve the financial returns we expect when we acquire renewable natural gas plants could have a material adverse effect on our ability to implement our growth strategy and, ultimately, our business, financial condition, and results of operations. Risks related to acquiring existing plants, include:

• the purchase price we pay could significantly deplete our cash reserves;

• the acquired companies or assets may not produce as planned or may entail significant unexpected or unbudgeted costs;

• we may have difficulty integrating the operations and personnel of the acquired companies;

• key personnel and customers of the acquired companies may terminate their relationships with the acquired companies as a result of or following the acquisition;

• we may experience additional financial and accounting challenges and complexities in areas such as joint venture accounting, tax planning, and financial reporting;

• we may incur additional costs and expenses related to complying with additional laws, rules or regulations in new jurisdictions;

• we may assume or be held liable for risks and liabilities (including for environmental-related costs) as a result of our acquisitions, some of which we may not discover during our due diligence or adequately adjust for in our acquisition arrangements;

• our ongoing business and management’s attention may be disrupted or diverted by transition or integration issues and the complexity of managing geographically diverse enterprises;

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• we may incur one-time write-offs or restructuring charges in connection with an acquisition;

• we may acquire goodwill and other intangible assets that are subject to amortization or impairment tests, which could result in future charges to earnings; and

• we may not be able to realize the expected cash flows or other financial benefits we anticipated.

Revenue from any renewable natural gas plants we complete may be adversely affected if there is a decline in public acceptance or support of renewable energy, or regulatory agencies, local communities, or other third parties delay, prevent, or increase the cost of constructing and operating our plants.

Certain persons, associations and groups could oppose renewable energy plants in general or our plants specifically, citing, for example, misuse of water resources, landscape degradation, land use, food scarcity or price increase and harm to the environment. Moreover, regulation may restrict the development of renewable energy plants in certain areas. Biogas production activities (both conventional natural gas and renewable natural gas) are subject to several environmental laws and regulations. The main environmental legislation governing environmental matters for our renewable natural gas developments is the Consolidated Environmental Act issued by Legislative Decree 152/2006.

We are also subject to authorization and permitting procedures which are outlined in Legislative Decree No. 28/2011, which offers three main pathways to permitting:

1. Notification: Used for minor modifications to existing renewable natural gas plants.

2. Simplified Authorization Procedure (S.A.P.): Applicable to:

• New plants with a production capacity under 500 standard cubic meters/hour.

• Converting existing power plants to biomethane production.

• Expanding existing renewable natural gas plants within certain limits.

3. Sole Authorization (S.A.): Required for projects outside the scope of S.A.P.

For S.A., applications are submitted to regional authorities, followed by a service conference involving relevant public bodies. The process typically concludes within 90 days, unless extended for assessments or document reviews. Under S.A.P., applications go to municipalities, with a decision required within 30 days; otherwise, approval is automatic. Recent legislative updates, like Law No. 95 of July 26, 2023, simplify authorization for biomethane projects, focusing on plants up to 500 smc/h, to facilitate faster connection to the national grid. These changes aim to streamline renewable natural gas development across Italy while ensuring environmental compliance.

Thus, in order to develop a renewable energy project, we are typically required to obtain, among other things, environmental impact permits or other authorizations and building permits, which in turn require environmental impact studies to be undertaken and public hearings and comment periods to be held during which any person, association or group may oppose a project. Any such opposition may be taken into account by government officials responsible for granting the relevant permits, which could result in the permits being delayed or not being granted or being granted solely on the condition that we carry out certain corrective measures to the proposed project. Opposition to our plants’ requests for permits or successful challenges or appeals to permits issued for our plants could adversely affect our operating plans.

As a result, we cannot guarantee that the renewable energy plants we currently plan to develop or, to the extent applicable, are developing, will ultimately be authorized or accepted by the local authorities or the local population. For example, the local population could oppose the construction of a renewable energy plant or infrastructure at the local government level, which could in turn lead to the imposition of more restrictive requirements. This type of negative response may lead to legal, public relations or other challenges that could impede our ability to meet our construction targets, achieve commercial operations for a project on schedule, address the changing needs of our plants over time or generate revenues.

If a significant portion of the local population were to mobilize against a renewable energy plant, it may become difficult, or impossible, for us to obtain or retain the required building permits and authorizations. Moreover, such challenges could result in the cancellation or modification of existing authorizations including, adoption of additional mitigation requirements or even, in extreme cases, the dismantling of existing renewable energy plants.

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Authorization for the use, construction, and operation of systems and associated transmission facilities on state and local lands will also require the assessment and evaluation of private rights-of-way, and other easements; environmental, agricultural, cultural, recreational, and aesthetic impacts; and the likely mitigation of adverse effects to these and other resources and uses. The inability to obtain the required permits and other state and local approvals, and any excessive delays in obtaining such permits and approvals due, for example, to litigation or third-party appeals, could potentially prevent us from successfully constructing and operating such plants in a timely manner and could result in the potential forfeiture of any deposit we have made with respect to a given project. Moreover, project approvals subject to project modifications and conditions, including mitigation requirements and costs, could affect the financial success of a given project. Changing regulatory requirements and the discovery of unknown site conditions could also adversely affect the financial success of a given project.

A decrease in acceptance of renewable energy plants by local populations, an increase in the number of legal challenges, or an unfavorable outcome of such legal challenges could adversely affect our business, financial condition and results of operations. We may also be subject to labor unavailability due to multiple simultaneous plants in a geographic region. If we are unable to grow and manage the capacity that we expect from our plants in our anticipated timeframes, it could adversely affect our business, financial condition and results of operations.

We may not be fully reimbursed for a portion of our renewable natural gas construction costs or may only receive payment on a delayed basis.

Under a recently implemented Italian renewable natural gas subsidy regime, we expect to be reimbursed for a portion of our capital expenditures related to our renewable natural gas development facilities. Such capital expenditure reimbursements are expected to reduce the amount of equity capital required as we grow our renewable natural gas asset portfolio. We expect to continue incurring significant acquisition and construction costs related to our renewable natural gas business. If policy is altered and such capital expenditure reimbursement subsidies are not available to us, if the timing of such reimbursements is delayed beyond our expectations, or if such expenditures are not reimbursable as we expect, it could significantly affect our cash flows and our development plan.

A prolonged environment of reduced demand for renewable natural gas or renewable electricity could have a material adverse effect on our long-term business prospects, financial condition and results of operations.

Long-term renewable natural gas and renewable electricity prices may fluctuate substantially due to factors outside of our control. The price of electricity can vary significantly for many reasons.

Demand can vary significantly for many reasons, including increases and decreases in generation capacity in our markets; changes in power transmission or fuel transportation capacity constraints or inefficiencies; power supply disruptions; weather conditions; seasonal fluctuations; changes in the demand for power or in patterns of power usage, including the potential development of demand-side management tools and practices; development of new fuels or new technologies for the production of power; and governmental regulations. Further, the amount of power consumed by the electric utility industry is affected primarily by the overall demand for electricity, environmental and other governmental regulations and the price and availability of fuels such as nuclear, coal, natural gas and oil, as well as sources of renewable energy. Slow growth or a long-term reduction in overall demand for energy could have a material adverse effect on our business strategy and could, in turn, have a material adverse effect on our business, financial condition and results of operations.

A policy revision with respect to the Italian government sponsored renewable natural gas floor price and renewable natural gas capital expenditure reimbursements could have a material adverse effect on our long-term business prospects, financial condition and results of operations.

A decline in prices for certain fuels or reduced Italian governmental incentives for renewable energy sources, or renewable natural gas specifically, could also make renewable natural gas less cost-competitive on an overall basis. If the price of alternative energy sources falls, including crude oil, any revenues that we generate from renewable natural gas could decline and we may be unable to produce products that are a commercially viable alternative to alternative energy sources. Further, throughout the central and southern EU (but primarily focused in Italy and Germany), member states’ interest in creating new sources of renewable energy has supported the construction of nearly 10,000 AD’s over the past 15 years. However, the Italian government’s financial incentives and subsidies supporting these activities are expected to be replaced by attractive biomethane incentives. Such incentives are designed to bring biomethane into the national pipeline transmission system in order to deliver the gas to higher efficiency, utility-scale, natural gas power

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generation stations. In order to continue biogas operations, the farms are forced to seek a new use for the product, which will be dominated by conversion to biomethane. To support this conversion, the Italian government has implemented a government-backed biomethane floor price through the end of 2039 of €124 per MWh, equivalent to $37.60 per (103ft3). If pricing of alternative energy sources becomes more favorable or the Italian government revises its energy policy to suspend or halt financial support of renewable natural gas, our business, financial condition and results of operations will be adversely affected.

We will face competition on the prices we receive for our renewable electricity and for rights to manage or develop renewable natural gas plants.

We will face competition from both conventional and renewable energy companies in connection with the prices that we can obtain for the renewable electricity we sell during the interim period before we complete the conversion of existing plants from electricity generation to renewable natural gas production and that we produce and sell into energy markets at market prices. The prices that these energy companies can offer are dependent on a variety of factors, including their fuel sources, transmission costs, capacity factor, technological advances and their operations and management. If these companies are able to offer their energy at lower prices, this will reduce the prices we are able to obtain in these markets, which could have a material adverse effect on our results of operations. Our competitors may also offer energy solutions at prices below cost, devote significant resources to competing with us or attempt to recruit our key personnel, any of which could improve their competitive positions. In addition, the technologies that we use may be rendered obsolete or uneconomic by technological advances, more efficient and cost-effective processes or entirely different approaches developed by one or more of our competitors or others. Moreover, if the demand for renewable energy increases, new companies may enter the market, and the influx of added competition could pose an increased risk to us.

In the renewable natural gas industry, we believe our primary competitors will be other renewable natural gas companies with existing plants and farm owners that either operate their own renewable natural gas plants or may do so in the future. Increased competition for such plants, equipment, and suppliers, may increase the price we pay for the acquisition costs for existing plants or the amount we have to pay farm owners in the form of equity interests or feedstock supply contracts, which may have a material adverse effect on our results of operations. We may also find ourselves competing more frequently with farm owners to the extent they decide to develop their own renewable natural gas plants, which would also reduce the number of opportunities for us to develop new renewable natural gas plants. While we anticipate receiving the subsidized floor price for our renewable natural gas, we may also compete with other renewable natural gas developers for production off-take agreements with existing and potential buyers of renewable natural gas.

Our renewable energy plants may not produce expected levels of output, and the amount of renewable natural gas actually produced at each of our plants will vary over time and, when a farm closes, eventually decline.

Farms contain organic material whose decomposition causes the generation of gas consisting primarily of methane, which renewable natural gas plants use to generate renewable natural gas or renewable electricity, and carbon dioxide. The estimation of renewable natural gas production volume is an inexact process and dependent on many site-specific conditions, including the estimated annual waste volume, composition of waste, regional climate and the capacity and construction of the farm. Production levels are subject to a number of additional risks, including illness and disease risks in the farm’s agriculture producing the waste feedstock, a failure or wearing out of our or our farm owners’ or operators’ equipment; an inability to find suitable replacement equipment or parts; lower than expected supply or quality of the project’s source of renewable natural gas and faster than expected diminishment of such renewable natural gas supply; or volume disruption in our fuel supply collection system. As a result, the amount of renewable natural gas actually produced by the farm sites from which our production facilities will collect renewable natural gas or the volume of electricity or renewable natural gas generated from those sites may in the future vary from our initial estimates, and those variations may be material.

In addition, the renewable natural gas available to our plants is dependent in part on the actions of other persons, such as farm operators. We may not be able to ensure the responsible management of the farm site by owners and operators, which may result in less feedstock to be used for the production of biomethane. Other events that can result in a reduction in renewable natural gas output include: extreme hot or cold temperatures or excessive rainfall; liquid levels within a farm increasing; oxidation within a farm, which can kill the anaerobic microbes that produce renewable natural gas; and the buildup of sludge. The occurrence of these or any other changes within any of the farms where our production facilities operate could lead to a reduction in the amount of renewable natural gas being available to operate our production facilities, which could have a material adverse effect on our business, financial condition and results of operations.

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We will be dependent on contractual arrangements with, and the cooperation of, farm site owners and operators for access to and operations on their sites.

While we expect to own the anaerobic digesters and upgrading units and underlying land on the farm sites in which our plants will operate, we will not own the entirety of farm sites and we may only own equipment and enter into surface or easement leases. Therefore, we may depend on contractual relationships with, and the cooperation of, the farm site owners and operators for our operations. We cannot guarantee that we will be able to renew any feedstock supply contracts that expire in the future on commercial terms that are attractive to us or at all, and any failure to do so, or any other disruption in the relationship with any of the farm operators from whose farm sites our plants reside on, may have a material adverse effect on our business operations, prospects, financial condition and operational results.

In addition, the ownership interests in the land subject to these easements, leases and rights-of-way may be subject to mortgages securing loans or other liens (such as tax liens) and other easements, lease rights and rights-of-way of third parties that were created prior to our plants’ easements, leases and rights-of-way. As a result, certain of our plants’ rights under these easements, leases or rights-of-way may be subject, and subordinate, to the rights of those third parties. In the event we do not own the land underlying our facilities, we may not be able to protect our operating plants against all risks of loss of our rights to use the land on which our plants are located, and any such loss or curtailment of our rights to use the land on which our plants are located and any increase in rent due on such lands could adversely affect our business, financial condition and results of operations.

The financial performance of our business depends upon tax and other governmental incentives for renewable energy generation, any of which could change at any time and such changes may negatively impact our growth strategy.

Our financial performance and growth strategy depend in part on government policies that support renewable generation and enhance the economic viability of owning renewable natural gas or renewable electric assets. If we are unable to utilize various government incentives to acquire additional renewable assets in the future, or the terms of such incentives are revised in a manner that is less favorable to us, we may suffer a material adverse effect on our business, financial condition, results of operations and cash flows.

We will rely on both pipeline and electrical interconnection and transmission facilities that we do not own or control and that are subject to transmission constraints within a number of our regions. If these facilities fail to provide us with adequate transmission capacity or have unplanned disruptions, we may be restricted in our ability to deliver electric power and renewable natural gas to our customers and we may either incur additional costs or forego revenues.

We depend on electric interconnection and transmission facilities and gas pipelines owned and operated by others to deliver the energy we generate at our plants to our customers. A failure or delay in the operation or development of these distribution channels or a significant increase in the costs charged by their owners and operators could result in the loss of revenues. Such failures or delays could limit the amount of energy our operating facilities deliver or delay the completion of our construction plants, which may also result in adverse consequences under our gas rights agreements and off-take agreements. Additionally, such failures, delays or increased costs could have a material adverse effect on our business, financial condition and results of operations.

Increased attention to environmental, social, and governance (“ESG”) matters may adversely impact our business.

Increased attention to climate change, circular economy, and other ESG matters, as well as investor and societal expectations regarding voluntary ESG disclosures and consumer expectations regarding sustainability may result in increased costs, reduced demand for our products, or other adverse impacts on our business, results of operations, and financial condition. For example, renewable natural gas faces competition from several other low-carbon energy technologies, such as solar or wind energy production, among others. Regulatory bodies may adopt rules that substantially favor certain energy alternatives over others, which may not always include renewable natural gas. Additionally, energy generation from the combustion of renewable natural gas results in GHG emissions. Fines, carbon taxes, or additional infrastructure to control methane emissions at both our conventional and renewable natural gas facilities may increase our costs. As such, certain consumers may elect not to consider renewable natural gas for their renewable energy or other ESG goals.

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In addition, organizations that provide information to investors on corporate governance and related matters have developed ratings processes for evaluating companies on their approach to ESG matters. Such ratings are used by some investors to inform their investment and voting decisions. Unfavorable ESG ratings and activism around our operations could lead to negative investor sentiment toward us and the renewable natural gas industry and to the diversion of investment capital to other industries, which could have a negative impact on our stock price and our access to and costs of capital. Also, certain institutional lenders may decide not to provide funding to us based on ESG concerns, which could adversely affect our operations, financial condition and access to capital for potential growth plants.

Maintenance, expansion and refurbishment of renewable natural gas facilities involve significant risks that could result in unplanned outages or reduced output.

Our future facilities may require periodic upgrading and improvement. Any unexpected operational or mechanical failure, including failure associated with breakdowns and forced outages, could reduce our facilities’ generating capacity below expected levels and reduce our revenue and cash flows. Unanticipated capital expenditures associated with maintaining, upgrading or repairing our facilities may also reduce profitability. If we make any major modifications to our facilities, such modifications could likely result in substantial additional capital expenditures. We may also choose to re-power, refurbish or upgrade our facilities based on our assessment that such activity will provide adequate financial returns. Such facilities require time for development and capital expenditures before commencement of commercial operations, and key assumptions underpinning a decision to make such an investment may prove incorrect, including assumptions regarding construction costs, timing, available financing and future renewable natural gas and renewable electricity prices. This could have a material adverse effect on our business, financial condition, results of operations and cash flows.

Risks Related to Foreign Operations and Regulatory Matters

Our primary operations are in another country and we are subject to political, economic and other uncertainties.

All of our natural gas assets and renewable gas assets are currently located in the country of Italy. Our operations in areas outside the United States are subject to various risks inherent in foreign operations. These risks may include, among other things:

• loss of revenue, property and equipment as a result of hazards such as expropriation, war, insurrection and other political risks;

• increases in taxes, including VAT taxes and potential future energy tax measures and governmental royalties;

• renegotiation of contracts with governmental entities;

• failure of the government to provide necessary permits within the anticipated timeframe, or at all;

• changes in laws and policies governing operations of foreign-based companies; and

• currency restrictions and exchange rate fluctuations.

Our international operations may also be adversely affected by laws and policies of the United States affecting foreign trade and taxation.

Realization of any of these factors could have a material adverse effect on our business, financial condition and results of operations.

We are subject to pricing restrictions enforced by the Italian Regulatory Authority for Energy, Networks and Environment with respect to the residential customers we intend to service.

AleAnna’s businesses are subject to regulatory risks mainly in Italy’s domestic market. The Italian Regulatory Authority for Energy, Networks and Environment (the “Authority”) is entrusted with certain powers in the matter of natural gas and power pricing. Specifically, the Authority retains a surveillance power on pricing in the natural gas market in Italy and the power to establish selling tariffs for the supply of natural gas to residential and commercial

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users who are opting for adhering to regulated tariffs until the market is fully opened. Developments in the regulatory framework intended to increase the level of market liquidity or of deregulation or intended to reduce operators’ ability to transfer to customers cost increases in raw materials may negatively affect future sales margins of gas and electricity, operating results, and cash flow.

All of our natural gas and renewable gas properties are located in country of Italy, making us vulnerable to risks associated with operating in one geographic area.

While we maintain access to acreage across Italy, all of our physical conventional natural gas assets, and most of our permits, are located in the Po Valley in Northern Italy and all of our current renewable natural gas assets are located in the region of Tuscany in Central Italy. As a result of this concentration, we may be disproportionately exposed to the impact of regional supply and demand factors, delays or interruptions of production from wells in this area caused by governmental regulation, appropriation and banning, processing or transportation capacity constraints, availability of equipment, facilities, personnel or services market limitations or interruption of the processing or transportation of natural gas. In addition, the effect of fluctuations on supply and demand may become more pronounced within specific geographic natural gas producing areas, which may cause these conditions to occur with greater frequency or magnify the effects of these conditions. We operate in geographic areas with a constantly evolving political landscape, to the extent regulatory regimes or prohibitions are implemented or return in the areas in which we operate, our business will be disproportionately affected due to our geographic concentration. Due to the concentrated nature of our portfolio of properties, a number of our properties could experience any of the same conditions at the same time, resulting in a relatively greater impact on our results of operations than they might have on other companies that have a more diversified portfolio of properties. Additionally, we do not hold title to our properties in Italy, but hold exploration permits and exploitation concessions granted by the Italian government. Under Italian law, each exploration permit is an exclusive right to explore for hydrocarbons and is subject to two renewals of three years each, being granted after the initial term of six years (article 6, paragraph 4, of Law 9/1991). To the extent we are unable to timely renew or obtain permits, our operations could be delayed or interrupted. Such delays or interruptions could have a material adverse effect on our business, financial condition and results of operations.

We have less control over our investments in foreign properties than we would have over domestic investments.

Our exploration, development and production activities are subject to various political, economic and other uncertainties, including but not limited to changes, sometimes frequent or marked, in energy policies or the personnel administering them, expropriation of property, cancellation or modification of contract rights, changes in laws and policies governing operations of foreign-based companies, unilateral renegotiation of contracts by governmental entities, uncertainties as to whether the laws and regulations will be applicable in any particular circumstance, uncertainty as to whether we will be able to demonstrate to the satisfaction of the applicable governing authorities compliance with governmental or contractual requirements, redefinition of international boundaries or boundary disputes, foreign exchange restrictions, currency fluctuations, foreign currency availability, royalty and tax increases, changes to tax legislation or the imposition of new taxes, the imposition of production bonuses or other charges and other risks arising out of governmental sovereignty over the areas in which our operations are conducted.

Our operations require, and any future opportunistic acquisitions may require, protracted negotiations with host governments, local governments and communities, local competent authorities, national companies, and third parties. Host governments may also conduct audits of our operations, the results of which may have a significant negative impact on our reported earnings or cash flows. Host governments may seek to participate in natural gas projects in a manner that could be diluted to our interests. Host governments may also require us to hire a specified percentage of local citizens in our operations. In addition, if a dispute arises with respect to our foreign operations, we may be subject to the exclusive jurisdiction of foreign courts or may not be successful in subjecting foreign persons, especially foreign ministries and national companies, to the jurisdiction of the U.S.

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We may expand our operations globally, which would subject us to additional anti-corruption, anti-bribery, anti-money laundering, trade compliance, economic sanctions and similar laws, and non-compliance with such laws may subject us to criminal or civil liability and harm our business, financial condition and/or results of operations. We may also be subject to governmental export and import controls that could impair our ability to compete in international markets or subject us to liability if we violate the controls.

If we expand our operations globally, we would be subject to the U.S. Foreign Corrupt Practices Act of 1977, as amended, U.S. domestic bribery laws, and other anti-corruption and anti-money laundering laws in the countries in which we would conduct business. Anti-corruption and anti-bribery laws have been enforced aggressively in recent years and are interpreted broadly to generally prohibit companies, their employees, and their third-party intermediaries from authorizing, offering, or providing, directly or indirectly, improper payments or benefits to recipients in the public or private sector. If we engage in international operations, sales and business with partners and third-party intermediaries to market our products, we may be required to obtain additional permits, licenses, and other regulatory approvals. In addition, we or our third-party intermediaries may have direct or indirect interactions with officials and employees of government agencies or state-owned or affiliated entities. If third-party intermediaries, or our employees, agents, representatives, contractors, or partners engage in violations while engaging in business on behalf of the Company, we may be subject to criminal or civil liability, even if we do not authorize such activities.

Our results of operations, financial condition and cash flows could be adversely affected by changes in currency exchange rates.

We are exposed to foreign currency risk from our foreign operations. A weakening U.S. dollar will have the effect of increasing costs, while a strengthening U.S. dollar will have the effect of reducing operating costs. The exchange rate between the Euro and the U.S. dollar has fluctuated widely in recent years in response to international political conditions, general economic conditions, the European sovereign debt crisis and other factors beyond our control. Our financial statements, presented in U.S. dollars, may be affected by foreign currency fluctuations through both translation risk and transaction risk.

We do not currently utilize derivative instruments to manage these foreign currency risks. As a result, our consolidated earnings and cash flows may be impacted by movements in the exchange rates.

Our results of operations, financial condition and cash flows could be adversely affected by changes in environmental laws and regulations.

Our operations must comply with intensive environmental laws and regulations. Increased regulation of environmental matters and the need to obtain stricter environmental local and governmental approvals and permits, might increase operational costs and timing and conditions of those approvals and permits.

Increased environmental standards, issues related to compliance with environmental regulations and decreased subsidies’ programs may curtail, delay or cancel our scheduled projects, or the development schedule.

Our business is and will be subject to issues related to compliance with environmental regulations, to environmental hazards, such as biomethane plant leaks, pipeline and tank ruptures, and unauthorized releases of toxic gases or other pollutants into the environment. Any of these risks could result in substantial losses due to personal injury and/or loss of life, severe damage to and destruction of property, equipment and natural resources, pollution or other environmental damage, disruptions to our operations, regulatory investigations and penalties, suspension of our operations, repair and remediation costs.

Risks Relating to our Organizational Structure, our Class A Common Stock and Public Warrants

We are a holding company and our organizational structure is what is commonly referred to as an Up-C structure, whereby all of the equity interests in AleAnna Energy are held by HoldCo and our sole material asset is our equity interest in HoldCo and we are accordingly dependent upon distributions from HoldCo to pay taxes, and cover our corporate and other overhead expenses.

We are a holding company and have no material assets other than our equity interest in HoldCo. We have no independent means of generating revenue. To the extent that we need funds and HoldCo or its subsidiaries are restricted from making such distributions under applicable law or regulation or under the terms of any financing or

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other contractual arrangements, or are otherwise unable to provide such funds, it could materially adversely affect our liquidity and financial condition. If HoldCo does not distribute sufficient funds to us to pay our taxes or other liabilities, we may default on contractual obligations or have to borrow additional funds. In the event that we are required to borrow additional funds, it could adversely affect our liquidity and subject us to additional restrictions imposed by lenders.

We anticipate that the distributions received from HoldCo may, in certain periods, exceed its actual tax liabilities and other financial obligations. Our Board of Directors (the “Board”), in its sole discretion, will make any determination from time to time with respect to the use of any such excess cash so accumulated. We will have no obligation to distribute such cash (or other available cash other than any declared dividend) to our stockholders.

In addition, the up-C structure confers certain benefits upon the members of HoldCo that will not benefit the holders of our Class A Common Stock to the same extent as it will benefit the HoldCo members. If HoldCo makes distributions to us, the HoldCo members will be entitled to receive equivalent distributions from HoldCo on a pro rata basis. However, because we must pay taxes, amounts ultimately distributed as dividends, if any in the future, to holders of our Class A Common Stock are expected to be less on a per share basis than the amounts distributed by HoldCo to its members on a per unit basis. This and other aspects of the up-C structure may adversely impact the trading market for your Class A Common Stock.

If HoldCo were to become a publicly traded partnership taxable as a corporation for U.S. federal income tax purposes, we and HoldCo might be subject to potentially significant tax inefficiencies.

We intend to operate such that HoldCo does not become a publicly traded partnership taxable as a corporation for U.S. federal income tax purposes. A “publicly traded partnership” is a partnership the interests of which are traded on an established securities market or are readily tradable on a secondary market or the substantial equivalent thereof. Under certain circumstances, the exchange of units of Class C HoldCo Units pursuant to (i) a holder’s right to exchange all or a portion of its Class C HoldCo Units, together with an equal number of Class C Common Stock, for shares of Class A Common Stock (the “ HoldCo Holder Redemption Right”) or (ii) the right of HoldCo upon a change of control of HoldCo or in the discretion of AleAnna with the consent of 50% of the holders of Class C HoldCo Units, to cause the exchange of all of the outstanding Class C HoldCo Units and an equal number of Class C Common Stock for shares of Class A Common Stock (a “Mandatory Exchange”) or (iii) other transfers of Class C HoldCo Units could cause HoldCo to be treated as a publicly traded partnership. Applicable U.S. Treasury regulations provide for certain safe harbors from treatment as a publicly traded partnership, and we intend to operate such that redemptions or other transfers of Class C HoldCo Units qualify for one or more of such safe harbors. For example, we limited the number of holders of Class C HoldCo Units, and the limited liability company agreement of HoldCo (the “A&R HoldCo LLC Agreement”), provides for certain limitations on the ability of holders of Class C HoldCo Units to transfer their Class C HoldCo Units and provides us, as the manager of HoldCo, with the right to prohibit the exercise of a HoldCo Holder Redemption Right if it determines (based on the advice of counsel) there is a material risk that HoldCo would be a publicly traded partnership as a result of such exercise.

If HoldCo were to become a publicly traded partnership taxable as a corporation for U.S. federal income tax purposes, significant tax inefficiencies might result for us and for HoldCo, including as a result of our inability to file a consolidated U.S. federal income tax return with HoldCo.

In certain circumstances, HoldCo is required to make tax distributions to the HoldCo unitholders, including us, and the tax distributions that HoldCo is required to make may be substantial. The HoldCo tax distribution requirement may complicate our ability to maintain our intended capital structure.

In certain circumstances, HoldCo may be required to make quarterly tax distributions to the HoldCo unitholders, including us. Such distributions are to be made pro rata and in an amount sufficient to cause each HoldCo unitholder to receive a distribution at least equal to such HoldCo unitholder’s allocable share of net taxable income (in the case of each HoldCo unitholder other than us, taking into account prior normal operating pro rata distributions made to such HoldCo unitholders in such year and calculated under certain assumptions) multiplied by an assumed tax rate. The assumed tax rate for this purpose will be the combined maximum U.S. federal, state, and local rate of tax applicable to us for the applicable taxable year unless otherwise determined by HoldCo. As a result of certain assumptions in calculating the tax distribution payments, we may receive tax distributions from HoldCo in excess of its actual tax liability.

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The receipt of such excess distributions would complicate our ability to maintain certain aspects of our capital structure. Such cash, if retained, could cause the value of a Class C HoldCo Unit to deviate from the value of a share of Class A Common Stock. If we retain such cash balances, the holders of Class C HoldCo Units would benefit from any value attributable to such accumulated cash balances as a result of their exercise of the HoldCo Holder Redemption Right or a Mandatory Exchange. We intend to take steps to eliminate any material cash balances. Such steps could include distributing such cash balances as dividends on our Class A Common Stock and reinvesting such cash balances in HoldCo for additional Class C HoldCo Units (with an accompanying stock dividend with respect to our Class A Common Stock or an adjustment to the one-to-one exchange ratio applicable to the exercise of the HoldCo Holder Redemption Right or a Mandatory Exchange).

The tax distributions to the HoldCo unitholders may be substantial and may, in the aggregate, exceed the amount of taxes that HoldCo would have paid if it were a similarly situated corporate taxpayer. Funds used by HoldCo to satisfy its tax distribution obligations will generally not be available for reinvestment in its business.

If we cannot meet the continued listing requirements of Nasdaq, Nasdaq may delist our securities.

As a public company, we are subject to the reporting requirements and the rules and regulations of the applicable listing standards of Nasdaq. If we fail to maintain compliance with the continued listing standards of Nasdaq, our securities may be delisted, which could negatively affect the market price and liquidity of our Class A Common Stock. In such case, we may seek to regain compliance by implementing a number of available options, including implementation of a reverse stock split to regain compliance with the Nasdaq’s minimum bid price requirement.

Volatility in the stock market may prevent investors from selling their securities at or above the price they paid for the shares.

The stock market is known for its volatility, and the market price of our securities may fluctuate significantly due to a number of factors that are both under our control and beyond our control. These factors include, among others, variations in our operating results, changes in expectations of future financial performance or changes in estimates of securities analysts, changes in the operating and stock price performance of other companies that investors deem comparable to us, and news reports relating to trends in our markets or general economic conditions. As a result, investors might not be able to sell their shares at or above the price they paid, which may result in substantial losses to the investor.

Our management team has limited recent experience in operating a public company.

Our executive officers have limited recent experience in the management of a publicly traded company. Our management team may not successfully or effectively manage our operations to comply with the regulatory oversight and reporting obligations under federal securities laws. We may not have adequate personnel with the appropriate level of knowledge, experience, and training in the policies, practices or internal controls over financial reporting required of public companies in the United States. As a result, we may be required to pay higher outside legal, accounting or consulting costs than our competitors, and our management team may have to devote a higher proportion of their time to issues relating to compliance with the laws applicable to public companies, both of which might put us at a disadvantage relative to competitors.

We are controlled by Nautilus, whose interests may conflict with ours and the interests of other stockholders.

Nautilus holds 84.85% of the voting power of AleAnna. Nautilus has the ability to determine all corporate actions requiring stockholder approval, including the election and removal of directors and the size of the Board, any amendment to our Certificate of Incorporation (the “Certificate of Incorporation”) or our Bylaws (the “Bylaws”), or the approval of any merger or other significant corporate transaction, including a sale of substantially all of our assets. This could have the effect of delaying or preventing a change in control or otherwise discouraging a potential acquirer from attempting to obtain control of us, which could cause the market price of our Class A Common Stock to decline or prevent stockholders from realizing a premium over the market price for our Class A Common Stock. The interests of Nautilus may conflict with our interests as a company or the interests of our other stockholders.

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We are a “controlled company” within the meaning of Nasdaq Capital Market rules and, as a result, qualify for exemptions from certain corporate governance requirements, and as a result, you will not have the same protections afforded to stockholders of companies that are not exempt from such corporate governance requirements.

Over 50% of our voting power for the election of directors is held by Nautilus. As a result, we are a controlled company within the meaning of Nasdaq Capital Market corporate governance standards. Under Nasdaq Capital Market rules, a controlled company may elect not to comply with certain Nasdaq corporate governance requirements, including the requirements that:

• a majority of the Board consist of independent directors under Nasdaq Capital Market rules;

• the nominating and governance committee be composed entirely of independent directors with a written charter addressing the committee’s purpose and responsibilities; and

• the compensation committee be composed entirely of independent directors with a written charter addressing the committee’s purpose and responsibilities.

These requirements will not apply to us as long as we remain a controlled company. We may utilize some or all of these exemptions. Accordingly, you may not have the same protections afforded to stockholders of companies that are subject to all of the corporate governance requirements of Nasdaq Capital Market.

The market price of our Class A Common Stock could be adversely affected by sales of substantial amounts of our Class A Common Stock in the public or private markets or the perception in the public markets that these sales may occur, including sales by the members of AleAnna Energy after the redemption of any Class C HoldCo Units, together with an equal number of our Class C Common Stock, in exchange for shares of our Class A Common Stock, or other large holders.

We have provided registration rights to certain large stockholders, including Nautilus, pursuant to the A&R Registration Rights Agreement (as defined herein). Sales of shares of our Class A Common Stock by Nautilus, including after the redemption of any Class C HoldCo Units, together with the cancellation of an equal number of our Class C Common Stock, for shares of our Class A Common Stock, or by other large holders of a substantial number of shares of our Class A Common Stock in the public markets following the business combination, or the perception that such sales might occur, could have a material adverse effect on the price of our Class A Common Stock or could impair our ability to obtain capital through an offering of equity securities in the future. Approximately 63,922,582 shares of Class A Common Stock are subject to registration rights in the Registration Rights Agreement.

Future sales and issuances of our Class A Common Stock could result in additional dilution of the percentage ownership of our stockholders and could cause our share price to fall.

We expect that additional capital may be needed in the future to pursue our growth plan. Particularly if natural gas prices negatively diverge from current levels or if our expectations around capital expenditure and operating costs are incorrect. To raise capital, we may sell shares of our Class A Common Stock, convertible securities or other equity securities in one or more transactions at prices and in a manner we determine from time to time. If we sell shares of our Class A Common Stock, convertible securities or other equity securities, investors may be materially diluted by subsequent sales. Such sales may also result in material dilution to our existing stockholders, and new investors could gain rights, preferences, and privileges senior to existing holders of our Class A Common Stock.

If our estimates or judgments relating to our critical accounting policies prove to be incorrect or financial reporting standards or interpretations change, our operating results could be adversely affected.

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (“GAAP”) requires management to make estimates, judgments, and assumptions that affect the amounts reported in our financial statements and accompanying notes. We base our estimates on historical experience and on various other assumptions that we believe to be reasonable under the circumstances. The results of these estimates form the basis for making judgments about the carrying values of assets, liabilities, and equity as of the date of the financial statements, and the amount of revenue and expenses, during the periods presented, that are not readily apparent from other sources. Significant assumptions and estimates used in preparing our financial statements include those related to impairment of intangible and long-lived assets, and share-based compensation.

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Our operating results may be adversely affected if our assumptions change or if actual circumstances differ from those in our assumptions, which could cause our operating results to fall below the expectations of industry or financial analysts and investors, resulting in a decline in the trading price of our Class A Common Stock.

Additionally, we regularly monitor our compliance with applicable financial reporting standards and review new pronouncements and drafts thereof that are relevant to us. As a result of new standards, changes to existing standards, and changes in interpretation, we might be required to change our accounting policies, alter our operational policies, or implement new or enhance existing systems so that they reflect new or amended financial reporting standards, or we may be required to restate our published financial statements. Changes to existing standards or changes in their interpretation may have an adverse effect on our reputation, business, financial position, and profit, or cause an adverse deviation from our revenue and operating profit target, which may negatively impact our financial results.

We have previously identified material weaknesses in our internal control over financial reporting. If we are unable to develop and maintain an effective system of internal control over financial reporting, we may not be able to accurately report the Company’s financial results in a timely manner, which may adversely affect investor confidence in us and materially and adversely affect our business and operating results, and we may face litigation as a result.

Effective internal controls are necessary to provide reliable financial reports and prevent fraud. AleAnna is a newly public company that is in the process of adding resources with the appropriate level of experience and technical expertise to oversee AleAnna’s business processes and controls. At this time, AleAnna does not have the necessary business processes and related internal controls formally designed and implemented.

As a result, AleAnna identified material weaknesses in its internal control over financial reporting. A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting such that there is a reasonable possibility that a material misstatement of annual or interim financial statements would not be prevented or detected on a timely basis.

In connection with the preparation of AleAnna’s financial statements as of and for the years ended December 31, 2024 and 2023, management of AleAnna identified material weaknesses in its internal control over financial reporting as follows:

• Management did not maintain an effective control environment in accordance with the COSO framework as it did not maintain a sufficient complement of accounting and reporting resources commensurate with its financial reporting requirements. This material weakness contributed to the following material weaknesses:

• Management did not design, implement, and operate controls over the selection and implementation of accounting policies to ensure amounts recorded and disclosed were fairly stated in accordance with GAAP.

• Management did not design or maintain appropriate account reconciliation and journal entry review controls to review the work of third-party consultants used to assist management in recording transactions.

We are in the early stages of designing and implementing a plan to remediate the material weaknesses identified. Our plan includes the below:

• Designing and implementing a risk assessment process supporting the identification of risks facing AleAnna.

• Implementing controls to enhance our review of significant accounting transactions and other new technical accounting and financial reporting issues and preparing and reviewing accounting memoranda addressing these issues.

• Hiring additional experienced accounting, financial reporting and internal control personnel and changing roles and responsibilities of our personnel as we transition to being a public company and are required to comply with Section 404 of the Sarbanes-Oxley Act.

• Implementing controls to enable an accurate and timely review of accounting records that support our accounting processes and maintain documents for internal accounting reviews.

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We cannot assure you that these measures will remediate the material weaknesses described above. The implementation of these remediation measures is in the early stages and will require validation and testing of the design and operating effectiveness of the Company’s internal controls over a sustained period of financial reporting cycles and, as a result, the timing of when the Company will be able to remediate the material weaknesses is uncertain and the Company may not remediate these material weaknesses during the year ended December 31, 2025. If the steps the Company takes do not remediate the material weaknesses in a timely manner, there could be a reasonable possibility that these control deficiencies or others may result in a material misstatement of its annual or interim financial statements that would not be prevented or detected on a timely basis. This, in turn, could jeopardize the Company’s ability to comply with its reporting obligations, limit its ability to access the capital markets and adversely impact its stock price.

As a result of becoming a public company, we are required to develop and maintain proper and effective internal control over financial reporting in order to comply with Section 404 of the Sarbanes-Oxley Act. We may not complete our analysis of our internal control over financial reporting in a timely manner, or these internal controls may not be determined to be effective, which may adversely affect investor confidence in us and, as a result, the value of our Class A Common Stock. In addition, because of our status as an emerging growth company, you will not be able to depend on any attestation from our independent registered public accountants as to our internal control over financial reporting for the foreseeable future.

We are required by Section 404 of the Sarbanes-Oxley Act to furnish a report by management on, among other things, the effectiveness of our internal control over financial reporting in our second annual report following the completion of the Business Combination. The process of designing and implementing internal control over financial reporting required to comply with this requirement will be time-consuming, costly and complicated. If during the evaluation and testing process we identify one or more other material weaknesses in our internal control over financial reporting our management will be unable to assert that our internal control over financial reporting is effective. In addition, if we fail to achieve and maintain the adequacy of our internal controls, as such standards are modified, supplemented or amended from time to time, we may not be able to ensure that we can conclude on an ongoing basis that we have effective internal controls over financial reporting in accordance with Section 404 of the Sarbanes-Oxley Act.

In addition, our independent registered public accounting firm will not be required to attest formally to the effectiveness of our internal control over financial reporting pursuant to Section 404 of the Sarbanes-Oxley Act for as long as we qualify for scaled “smaller reporting company” disclosure under the Exchange Act. Accordingly, you will not be able to depend on any attestation concerning our internal control over financial reporting from our independent registered public accountants for the foreseeable future.

We cannot be certain as to the timing of completion of our evaluation, testing and any remediation actions or the impact of the same on our operations. If we are not able to implement the requirements of Section 404 of the Sarbanes-Oxley Act in a timely manner or with adequate compliance. As a result, there could be a negative reaction in the financial markets due to a loss of confidence in the reliability of our financial statements. In addition, we may be required to incur costs in improving our internal control system and the hiring of additional personnel. Any such action could negatively affect our results of operations and cash flows.

We do not have experience operating as a public company subject to U.S. federal securities laws and may not be able to adequately develop and implement the governance, compliance, risk management and control infrastructure and culture required for a public company, including compliance with the Sarbanes-Oxley Act.

We do not have experience operating as a public company subject to U.S. federal securities laws. Our officers and directors have limited recent experience in managing a public company subject to U.S. federal securities laws, which makes their ability to comply with applicable laws, rules and regulations uncertain. Our failure to comply with all applicable laws, rules and regulations could subject us to U.S. regulatory scrutiny or sanction, which could harm its reputation and share price.

AleAnna has not previously been required to prepare or file periodic or other reports with the SEC or to comply with the other requirements of U.S. federal securities laws. Additionally, AleAnna has not previously been required to establish and maintain the disclosure controls and procedures, and internal control over financial reporting applicable to a public company under U.S. federal securities laws, including the Sarbanes-Oxley Act. We may experience errors, mistakes and lapses in processes and controls, resulting in failure to meet requisite U.S. standards.

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As a public company subject to U.S. federal securities laws, we will incur significant legal, accounting, insurance, compliance, and other expenses. Compliance with reporting, internal control over financial reporting and corporate governance obligations may require members of our management and our finance and accounting staff to divert time and resources from other responsibilities to ensure these new regulatory requirements are fulfilled.

If we fail to adequately implement the required governance and control framework, we may fail to comply with the applicable rules or requirements associated with being a public company subject to U.S. federal securities laws. Such failure could result in the loss of investor confidence, could harm our reputation, and cause the market price of our Class A Common Stock, and any other securities it may list in the future, to decline.

Due to inadequate governance and internal control policies, misstatements or omissions due to error or fraud may occur and may not be detected, which could result in failures to make required filings in a timely manner or result in making filings containing incorrect or misleading information. Any of these outcomes could result in SEC enforcement actions, monetary fines or other penalties, as well as damage to our reputation, business, financial condition, operating results and share price.

The JOBS Act permits “emerging growth companies” like us to take advantage of certain exemptions from various reporting requirements applicable to other public companies that are not emerging growth companies.

We qualify as an “emerging growth company” as defined in Section 2(a)(19) of the Securities Act of 1933, as amended (the “Securities Act”), as modified by the JOBS Act. As such, we take advantage of certain exemptions from various reporting requirements applicable to other public companies that are not emerging growth companies, including (i) the exemption from the auditor attestation requirements with respect to internal control over financial reporting under Section 404 of the Sarbanes-Oxley Act, (ii) the exemptions from say-on-pay, say-on-frequency and say-on-golden parachute voting requirements and (iii) reduced disclosure obligations regarding executive compensation in our periodic reports and registration statements. As a result, our stockholders may not have access to certain information they deem important. We will remain an emerging growth company until the earliest of (i) the last day of the fiscal year (a) following the fifth anniversary of the closing of SPAC’s IPO, which is December 14, 2021, (b) in which we have total annual gross revenue of at least $1.235 billion, or (c) in which we are deemed to be a large accelerated filer, which means the market value of our common equity that is held by non-affiliates exceeds $700 million as of the end of the prior fiscal year’s second fiscal quarter; and (ii) the date on which we have issued more than $1.00 billion in non-convertible debt securities during the prior three-year period. References herein to “emerging growth company” shall have the meaning associated with it in the JOBS Act.

In addition, Section 107 of the JOBS Act provides that an emerging growth company can take advantage of the exemption from complying with new or revised accounting standards provided in Section 7(a)(2)(B) of the Securities Act as long as we are an emerging growth company. An emerging growth company can therefore delay the adoption of certain accounting standards until those standards would otherwise apply to private companies. The JOBS Act provides that a company can elect to opt out of the extended transition period and comply with the requirements that apply to non-emerging growth companies, but any such election to opt out is irrevocable. We have elected not to irrevocably opt out of such extended transition period, which means that when a standard is issued or revised and it has different application dates for public or private companies, we may adopt the new or revised standard at the time public companies adopt the new or revised standard.

Because we have no current plans to pay regular cash dividends on our Class A Common Stock, you may not receive any return on investment unless you sell your Class A Common Stock for a price greater than that which you paid for it.

We do not anticipate paying any regular cash dividends on our Class A Common. Any decision to declare and pay dividends in the future will be made at the discretion of our Board and will depend on, among other things, our results of operations, financial condition, cash requirements, contractual restrictions and other factors that our Board may deem relevant. In addition, our ability to pay dividends may in the future be limited by covenants of existing and any future outstanding indebtedness we or our subsidiaries incur. Therefore, any return on investment in our Class A Common Stock is solely dependent upon the appreciation of the price of our Class A Common Stock on the open market, which may not occur.

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If securities or industry analysts do not publish or cease publishing research or reports about us, our business or our market, or if they change their recommendations regarding our Class A Common Stock adversely, the price and trading volume of our Class A Common Stock could decline.

The trading market for our shares of our Class A Common Stock will be influenced by the research and reports that industry or securities analysts may publish about us, our business, our market or our competitors. If any of the analysts who may cover us change their recommendation regarding our stock adversely, or provide more favorable relative recommendations about our competitors, the price of our shares of our Class A Common Stock would likely decline. If any analyst who may cover us were to cease their coverage or fail to regularly publish reports on us, we could lose visibility in the financial markets, which could cause our stock price or trading volume to decline.

Our Certificate of Incorporation designates the Court of Chancery of the State of Delaware as the exclusive forum for certain litigation that may be initiated by our shareholders, which could limit our shareholders’ ability to obtain a favorable judicial forum for disputes with us.

Pursuant to our Certificate of Incorporation, unless we consent in writing to the selection of an alternative forum, the Court of Chancery of the State of Delaware will be the sole and exclusive forum for (i) any derivative action or proceeding brought on behalf of us, (ii) any action asserting a claim of breach of a fiduciary duty owed by any of our directors, officers, employees or agents to us or our stockholders, (iii) any action or proceeding asserting a claim against us arising pursuant to any provision of the Delaware General Corporation Law (“DGCL”) or the Certificate of Incorporation or our Bylaws, (iv) any action to interpret, apply, enforce or determine the validity of the our Certificate of Incorporation or our Bylaws or (v) any action or proceeding asserting a claim against us governed by the internal affairs doctrine, in each case subject to said Court of Chancery having personal jurisdiction over the indispensable parties named as defendants therein. The forgoing provisions will not apply to any claims arising under the Exchange Act or the Securities Act and, unless we consent in writing to the selection of an alternative forum, the federal district courts of the United States of America will be the sole and exclusive forum for resolving any action asserting a claim arising under the Securities Act.

This choice of forum provision in our Certificate of Incorporation may limit a shareholder’s ability to bring a claim in a judicial forum that it finds favorable for disputes with us or any of our directors, officers, or other employees, which may discourage lawsuits with respect to such claims. There is uncertainty as to whether a court would enforce such provisions, and the enforceability of similar choice of forum provisions in other companies’ charter documents has been challenged in legal proceedings. It is possible that a court could find these types of provisions to be inapplicable or unenforceable, and if a court were to find the choice of forum provision contained in the Certificate of Incorporation to be inapplicable or unenforceable in an action, we may incur additional costs associated with resolving such action in other jurisdictions, which could harm our business, results of operations and financial condition. These exclusive-forum provisions may limit a shareholder’s ability to bring a claim in a judicial forum that it finds favorable for disputes with us or our directors, officers, or other employees and this limitation may have the effect of discouraging lawsuits or make our securities less attractive to investors. Further, while the Delaware courts have determined that such choice of forum provisions are facially valid, a shareholder may nevertheless seek to bring such a claim arising under the Securities Act against our directors, officers, or other employees in a venue other than in the federal district courts of the United States of America. In such instance, we would expect to vigorously assert the validity and enforceability of the exclusive forum provisions of the Certificate of Incorporation. This may require significant additional costs associated with resolving such action in other jurisdictions and we cannot assure you that the provisions will be enforced by a court in those other jurisdictions. If a court were to find either exclusive-forum provision in our Certificate of Incorporation to be inapplicable or unenforceable in an action, it may incur further significant additional costs associated with resolving the dispute in other jurisdictions, all of which could harm our business.

The Company may redeem unexpired Public Warrants prior to their exercise at a time that is disadvantageous to the holder, thereby making the Public Warrants worthless.

We have the ability to redeem the outstanding Public Warrants at any time after they become exercisable and prior to their expiration, at a price of $0.01 per Public Warrant, if, among other things, the last sales price of our Class A Common Stock equals or exceeds $18.00 per share for a period of 20 trading days within any 30 trading day period (as adjusted for adjustments to the number of shares issuable upon exercise or the exercise price of a Public Warrant as described in the section titled “Description of Securities” in this Registration Statement on Form S-1). If and when the Public Warrants become redeemable by us, we may exercise our redemption right. Redemption of the

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outstanding Public Warrants as described above could force holders to (i) exercise the Public Warrants and pay the exercise price therefor at a time when it may be disadvantageous for holders to do so, (ii) sell the Public Warrants at the then-current market price when holders might otherwise wish to hold the Public Warrants or (iii) accept the nominal redemption price which, at the time the outstanding Public Warrants are called for redemption, we expect would be substantially less than the market value of the Public Warrants.

We have the ability to require holders of the Public Warrants to exercise such Public Warrants on a cashless basis, which will cause holders to receive fewer shares of Class A Common Stock upon their exercise of the Public Warrants than they would have received had they been able to exercise their Public Warrants for cash.

If the Company calls the Public Warrants for redemption after the redemption criteria described elsewhere in this prospectus have been satisfied, we have the option to require any holder that wishes to exercise their Public Warrants to do so on a “cashless basis.” If the Company’s management chooses to require holders to exercise their Public Warrants on a cashless basis, the number of our Class A Common Stock received by a holder upon exercise will be fewer than it would have been had such holder exercised the Public Warrant for cash. This will have the effect of reducing the potential “upside” of the holder’s investment in the Company.

The exclusive forum clause set forth in the warrant agreement governing the Public Warrants may have the effect of limiting an investor’s rights to bring legal action against us and could limit the investor’s ability to obtain a favorable judicial forum for disputes with us.

Our outstanding Public Warrants provide for investors to consent to exclusive forum to state or federal courts located in New York, New York. This exclusive forum may have the effect of limiting the ability of investors to bring a legal claim against us due to geographic limitations and may limit an investor’s ability to bring a claim in a judicial forum that it finds favorable for disputes with us. Alternatively, if a court were to find this exclusive forum provision inapplicable to, or unenforceable in respect of, one or more of the specified types of actions or proceedings, we may incur additional costs associated with resolving such matters in other jurisdictions, which could adversely affect our business and financial condition. Notwithstanding the foregoing, nothing in the warrant limits or restricts the federal district court in which a holder of a warrant may bring a claim under the federal securities laws.

Our business and operations could be negatively affected if we become subject to any securities litigation or shareholder activism, which could cause us to incur significant expense, hinder execution of business and growth strategy and impact our stock price.

In the past, following periods of volatility in the market price of a company’s securities, securities class action litigation has often been brought against that company. Shareholder activism, which could take many forms or arise in a variety of situations, has been increasing recently. Volatility in the stock price of our Class A Common Stock or other reasons may in the future cause it to become the target of securities litigation or shareholder activism. Securities litigation and shareholder activism, including potential proxy contests, could result in substantial costs and divert management’s and the Board’s attention and resources from our business. Additionally, such securities litigation and shareholder activism could give rise to perceived uncertainties as to our future, adversely affect our relationships with service providers and make it more difficult to attract and retain qualified personnel. Also, we may be required to incur significant legal fees and other expenses related to any securities litigation and activist shareholder matters. Further, our stock price could be subject to significant fluctuation or otherwise be adversely affected by the events, risks and uncertainties of any securities litigation and shareholder activism.

A substantial number of the Company’s Class A Common Stock are restricted securities and as a result, there may be limited liquidity for our Class A Common Stock.

A substantial portion of our outstanding shares of Class A Common Stock currently constitute restricted securities and “control” securities for purposes of Rule 144 of the Securities Act or are otherwise subject to a contractual lockup. As a result, there may initially be limited liquidity in the trading market for our Class A Common Stock until these shares are sold pursuant to an effective registration statement under the Securities Act or the shares become available for resale without volume limitations or other restrictions under Rule 144 and are otherwise no longer subject to a lockup agreement. Even once these are no longer restricted or a registration statement for such shares has become effective, the liquidity for our Class A Common Stock may remain limited given the substantial holdings of such stockholders, which could make the price of our Class A Common Stock more volatile and may make it more difficult for investors to buy or sell large amounts of our Class A Common Stock.

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Future resales of our Class A Common Stock may cause the market price of our Class A Common Stock to drop significantly, even if the Company’s business is doing well.

AleAnna Energy’s pre-Business Combination equity holders hold the substantial majority of our outstanding Class A Common Stock. The resale, or expected or potential resale, of a substantial number of our Class A Common Stock in the public market could adversely affect the market price for our Class A Common Stock and make it more difficult for you to sell your Class A Common Stock at times and prices that you feel are appropriate.

Further, sales of our Class A Common Stock upon expected expiration of resale restrictions could encourage short sales by market participants. Generally, short selling means selling a security, contract or commodity not owned by the seller. The seller is committed to eventually purchase the financial instrument previously sold. Short sales are used to capitalize on an expected decline in the security’s price. As such, short sales of our Class A Common Stock could have a tendency to depress the price of our Class A Common Stock, which could further increase the potential for short sales.

If our existing shareholders sell or indicate an intention to sell substantial amounts of our Class A Common Stock in the public market, the trading price of our Class A Common Stock could decline. In addition, shares underlying any future outstanding options and restricted stock units will become eligible for sale if exercised or settled, as applicable, and to the extent permitted by the provisions of various vesting agreements and Rule 144 of the Securities Act. The Company may also issue shares in the ordinary course of its business, and cannot predict the size of future issuances or sales of our Class A Common Stock or the effect, if any, that future issuances and sales of our Class A Common Stock will have on the market price of our Class A Common Stock. Sales of substantial amounts of our Class A Common Stock, including issuances made in the ordinary course of the Company’s business, or the perception that such sales could occur, may materially and adversely affect prevailing market prices of our Class A Common Stock. If these additional shares are sold, or if it is perceived that they will be sold in the public market, the trading price of our Class A Common Stock could decline.

Although Sponsor and certain other holders of our Class A Common Stock are subject to certain restrictions regarding the transfer of our Class A Common Stock, these shares may be sold after the expiration of their respective lock-ups. We intend to file one or more registration statements to provide for the resale of such shares from time to time. As restrictions on resale end and the registration statements are available for use, the market price of our Class A Common Stock could decline if the holders of currently restricted shares sell them or are perceived by the market as intending to sell them. In addition, registration rights we may grant in the future, including in the ordinary course of the Company’s business, may further depress market prices if these registration rights are exercised or shares of our Class A Common Stock are sold under the registration statements, the presence of additional shares trading in the public market may also adversely affect the market price of our Class A Common Stock.

We may engage in future acquisitions or strategic transactions, which may not be integrated into our business successfully.

We anticipate that we will continue to explore, opportunities to create value through strategic transactions, whether through mergers and acquisitions, divestitures, joint ventures or similar business transactions. There are risks inherent in any strategic transaction, and such risks could negatively affect the benefits, outcomes and synergies anticipated to be obtained from executing such strategic transactions.

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USE OF PROCEEDS

We may receive up to approximately $129.1 million, assuming the exercise in full of all of the Public Warrants for cash. As of April 16, 2025, we have received an aggregate of approximately $276,356.50 in cash proceeds upon exercise of Public Warrants. Pursuant to the terms of the Public Warrants, no cashless exercise will be permitted unless the fair market value is equal to or higher than the warrant price. The likelihood that holders of Public Warrants will exercise their Public Warrants and the amount of any cash proceeds that we would receive is dependent upon the market price of our Class A Common Stock. If the market price for our Class A Common Stock is less than $11.50 per share, we believe holders of Public Warrants will be unlikely to exercise their Public Warrants. Under certain circumstances, the Public Warrants may be exercised on a cashless basis. If the Public Warrants are exercised on a cashless basis, we will not receive any cash from these exercises. Unless we inform you otherwise in a prospectus supplement, we expect to use any net proceeds from the exercise of the Public Warrants for general corporate purposes.

We will not pay any brokers’ or underwriters’ discounts and commissions in connection with the registration and sale of the Class A Common Stock covered by this prospectus. We will bear all other costs, fees and expenses incurred in effecting the registration of such securities covered by this prospectus, including, without limitation, all registration and filing fees, Nasdaq listing fees, and fees of our counsel and our independent registered public accountants.

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MARKET INFORMATION FOR COMMON STOCK AND DIVIDEND POLICY

Market Information

AleAnna’s Class A Common Stock and Public Warrants are listed on Nasdaq, respectively, under the symbols “ANNA” and “ANNAW,” respectively. Our Class A Common Stock and Public Warrants began public trading on December 16, 2024.

On April 15, 2025, the last sale price of the Class A Common Stock and the Public Warrants as reported on the Nasdaq were $12.57 per share and $0.27 per warrant, respectively.

As of April 16, 2025, there were (i) 40,584,455 shares of Class A Common Stock issued and outstanding and held of record by 43 holders, (ii) 25,994,400 shares of Class C Common Stock issued and outstanding and held of record by one holder, and (iii) 11,225,969 Public Warrants to acquire 11,225,969 shares of Class A Common Stock and held of record by one holder. There were no shares of Class B Common Stock outstanding. The number of record holders does not include The Depository Trust Company participants or beneficial owners holding shares or Warrants through banks, brokers, other financial institutions or other nominees.

Dividend Policy

We have not declared or paid any dividends on our Class A Common Stock. We currently do not anticipate paying cash dividends on our Class A Common Stock for the foreseeable future. Any decision to declare and pay dividends on our Class A Common Stock in the future will be made at the sole discretion of our Board and will depend on, among other things, our results of operations, cash requirements, financial condition, contractual restrictions, including those under any current or future debt instruments, and other factors that our board of directors may deem relevant.

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MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS

The following discussion and analysis of our financial condition and results of operations should be read together with our consolidated financial statements and the related notes appearing elsewhere in this prospectus. The discussion and analysis should also be read together with the section entitled “Business” and our pro forma financial information. See “Unaudited Pro Forma Combined Financial Information.” This discussion and analysis contains forward-looking statements that reflect our plans, estimates and beliefs that involve risks and uncertainties that may be outside our control. As a result of many factors, such as those set forth under the headings “Risk Factors” and elsewhere in this prospectus, our actual results may differ materially from those anticipated in these forward-looking statements. Unless the context otherwise requires, all references in this section to “we,” “us,” “our,” “AleAnna,” or the “Company” refer to AleAnna, Inc.

Overview

AleAnna is a natural gas resource company focused on delivering critical natural gas supplies to Europe through both onshore conventional natural gas exploration and renewable natural gas development in Italy. We have several conventional natural gas discoveries including, the Longanesi field, located in the Po Valley in Northern Italy, which is one of Italy’s largest modern gas discoveries. We retain a 33.5% working interest in the Longanesi field with our working interest partner, and operator, Padana. We acquired our working interest in the Longanesi field through a 2016 transaction with Enel. We also retain wholly owned concessions, permits, and pending applications on other exploration and development prospects across Italy which are supported by proprietary modern 3D seismic reservoir imaging. In 2021, we launched a renewable natural gas development business focused on bringing to market carbon-negative renewable natural gas derived from animal and agricultural waste.

Planned principal operations have not yet commenced. As of December 31, 2024, although we had generated revenue from electricity sales from two renewable natural gas assets, we had not generated any revenues from our principal business activities to date. Our recent activities involve the drilling and testing of three Longanesi development wells (2022 and 2023) as well as the completion of two original discovery wells. We had no drilling activity during the year ended December 31, 2024, and drilled and completed one gross Longanesi development well and worked over and completed one additional Longanesi development well (0.335 net to our interest) during the year ended December 31, 2023. We had no other exploratory or development drilling the years ended December 31, 2024 or 2023. Our Longanesi, Trava and Gradizza wells were classified by DeGolyer & MacNaughton (“DeGolyer”) as proved undeveloped reserves as such wells had not yet started production as of December 31, 2024 and require future investments to install production pipelines and production facilities prior to being fully completed and producible. Following tie-in of these wells and the installation of a temporary processing facility, we and Padana achieved first production of the five wells in the Longanesi field in March 2025. The permanent processing facility is expected to be constructed over the remainder of 2025 and early 2026 and commissioned in mid-2026.

The Transactions

On December 13, 2024, we consummated the previously announced business combination pursuant to the Agreement and Plan of Merger (as amended, the “Merger Agreement”), dated June 4, 2024, by and among Swiftmerge Acquisition Corp., a Cayman Islands exempted company (“Swiftmerge” or “SPAC”), Swiftmerge HoldCo LLC, a Delaware limited liability company and wholly-owned subsidiary of Swiftmerge (“HoldCo”), Swiftmerge Merger Sub LLC, a Delaware limited liability company and wholly-owned subsidiary of HoldCo, and AleAnna Energy, LLC, a Delaware limited liability company (“AleAnna Energy”). Pursuant to the terms of the Merger Agreement, on December 13, 2024, SPAC migrated to and domesticated as a Delaware corporation in accordance with Section 388 of the Delaware General Corporation Law, as amended, and the Companies Act (As Revised) of the Cayman Islands and changed its name to AleAnna, Inc. The transactions contemplated by the Merger Agreement are collectively referred to herein as the “Business Combination.”

The Business Combination was accounted for as a common control transaction with respect to AleAnna Energy which is akin to a reverse recapitalization. This conclusion was based on the fact that Nautilus Resources LLC (“Nautilus”) had a controlling financial interest in AleAnna Energy prior to the Business Combination and has a controlling financial interest in AleAnna, which includes AleAnna Energy as a wholly owned subsidiary. The net assets of SPAC are stated at their historical carrying amounts with no goodwill or intangible assets recognized

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in accordance with the accounting principles generally accepted in the United States of America (“GAAP”). The Business Combination with respect to AleAnna Energy was not treated as a change in control primarily due to Nautilus receiving the controlling voting stake in AleAnna and the ability of Nautilus to nominate the full board of directors and management of AleAnna.

Under a reverse recapitalization, SPAC is treated as the “acquired” company for financial reporting purposes. Accordingly, for accounting purposes, the Business Combination is treated as the equivalent of AleAnna Energy issuing stock for the net assets of SPAC, accompanied by a recapitalization.

We incurred $9.5 million in transaction costs related to the Business Combination. Approximately $0.6 million of these costs were recorded as a reduction to additional paid-in capital, up to the amount of cash proceeds received in the transaction. Of the remaining $8.9 million, approximately $0.5 million represented prepaid directors and officers insurance premiums that were recorded to other assets in the consolidated balance sheet, and $8.4 million represented legal, accounting, consulting and advisory fees which were recorded as Business Combination transaction expenses in the consolidated statement of operations and comprehensive loss.

Recent Developments

First Production at Longanesi

On March 13, 2025, AleAnna achieved a key milestone with the first production from its five wells in the Longanesi field.

In connection with this milestone, AleAnna will be required to reserve $3.1 million related to the contingent consideration liability due to Enel (see Note 6). These funds will be classified as restricted cash in future balance sheets and may be used to satisfy the contingent consideration liability as payments become due.

Gas Sale Agreement

On October 29, 2024, we entered into a gas sale agreement (“GSA”) with Shell Energy Europe Limited (“SEEL”), whereby SEEL became the exclusive buyer of our share of the natural gas produced from the Longanesi field net of (i) any consumption and/or losses incurred in the transport, treatment and compression of gas before delivery; (ii) any volume to be allocated for regulated royalties auctions, if applicable; and (iii) any other volume contractually allocated to other parties before August 31, 2022. Future sales under the GSA are contingent upon the commencement of gas production.

Renewable Natural Gas Acquisitions

Between March 2024 and July 2024, we successfully completed three separate strategic acquisitions of renewable natural gas plant projects in Italy for an aggregate of approximately $9.5 million. The plants are fully permitted and are in various stages of the development lifecycle, with one greenfield plant (Campagnatico) that is a new development and two brownfield plants (Casalino and Campopiano) that are currently operational.

Capital Contributions

Between January 2024 and May 2024, we received an aggregate of $62.1 million in capital contributions from our members, resulting in the issuance of 62,100 Class 1 Preferred Units, to fund operating costs and capital expenditures and provide working capital to meet our liabilities and commitments as they become due for at least the upcoming 12 months. These capital contributions were the final capital contributions to AleAnna Energy before the Business Combination and that all equity of AleAnna Energy, including the Class 1 Preferred Units, were exchanged for Class A and Class C Common stock as part of the December 13, 2024. We are using these funds to fulfill the Longanesi gas pipeline and plant activity obligations, as well as general and administrative expenses.

Blugas Settlement

On May 28, 2024, we reached a settlement agreement (the “Blugas Settlement Agreement”) with Blugas Infrastructure S.r.l. (“Blugas”) regarding the Blugas overriding royalty interest (“ORRI”) whereby Blugas was entitled to physical delivery of 20% of the first 350 million standard cubic meters (approximately 2,472 106ft3) produced from

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the Longanesi field. Under the terms of the Blugas Settlement Agreement, we paid Blugas approximately €5 million, plus an additional €1.1 million in applicable VAT. In exchange, we were released from any future liability related to the Blugas ORRI. As a result of the transactions contemplated by the Blugas Settlement Agreement, our 33.5% working interest (net revenue interest) in the Longanesi field, as established under the terms of the Unified Operating Agreement arrangement originally signed between ENI and Grove and dated September 26, 2009, is now unencumbered except for normal government royalties (10%). The Blugas Settlement Agreement was accounted for as an acquisition of the Blugas ORRI claim with a corresponding increase to the expected future cash flows from our reserves. Our year-end December 31, 2023 reserve quantities included the 20% of 350 million standard cubic meters (approximately 2,472 106ft3) allocable to the Blugas ORRI in our proved gas reserves. However, the required payments to Blugas associated with the sale of such quantities were reflected as cash outflows (costs) in our year-end December 31, 2023 reserve report as if such amounts were paid to Blugas. Following settlement, our year-end December 31, 2024 reserve quantities continue to include the 20% of 350 million standard cubic meters (approximately 2,472 106ft3), however, the previously required payments to Blugas associated with the sale of such quantities are no longer reflected as cash outflows (costs) as if such amounts were paid to Blugas. As the cash outflows (costs) are no longer reflected as if paid to Blugas, such amounts are reflected in our December 31, 2024 reserve report as allocable to our unencumbered 33.5% working interest.

Key Factors Affecting our Performance, Prospects and Future Results

We believe that our performance and future success depend on a number of factors that present significant opportunities for us but also pose risks and challenges, including competition from other carbon-based and non-carbon-based fuel producers, regulatory hurdles posed by the Italian government, and other factors discussed under the section titled “Risk Factors.” We believe the factors described below are key to our success.

Achieving First Production at Longanesi

As previously discussed, we and Padana achieved first production of the five wells in the Longanesi field in the first quarter of 2025 through use of a temporary processing facility. The permanent processing facility is expected to be constructed over the remainder of 2025 and early 2026 and commissioned mid-2026.

We believe our achieving first production of the Longanesi field is a key milestone that will fuel our potential growth. We also have potentially viable discoveries in our Gradizza and Trava fields that are expected to achieve first production in the future.

Commencing and Expanding Renewable Natural Gas Operations

In 2021, we launched a renewable natural gas development business focused on bringing to market carbon negative renewable natural gas derived from animal and agricultural waste. As previously discussed, the first three renewable natural gas assets were purchased between March 2024 and July 2024, with additional renewable natural gas projects expected to be purchased in the future.

We believe expanding the renewable natural gas business is another key to our potential growth and may unlock potential partnership or joint venture opportunities.

Key Components of Results of Operations

We are an early-stage company and our historical results may not be indicative of our future results. Accordingly, the drivers of our future financial results, as well as the components of such results, may not be comparable to our historical results of operations or our future results of operations.

Revenue

During the year ended December 31, 2024, we generated approximately $1.4 million of revenue from electricity sales at two renewable natural gas assets acquired in July 2024 (the “Casalino” and “Campopiano” plants). The plant assets are fully permitted for production of electricity through conversion of crop and animal waste bio feedstocks. The plant assets are currently biomethane to electricity conversion assets. It is our intention to begin upgrading the sites to refine biomethane into renewable natural gas through upgrading units. Following the upgrade process to

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transition the assets to biomethane to renewable natural gas conversion, we expect to sell renewable natural gas to customer(s) by trucking or piping the renewable natural gas to the interstate pipeline system (SNAM). Until the plant assets are upgraded, we will actively source bio feedstocks for the assets in order to produce biomethane which will be processed through reciprocating generators in order to generate electricity which is then sold onto the grid through a metered interconnection. Casalino and Campopiano derive revenues from the sale of such electricity to the local state-owned electrical utility (Gestore dei Servizi Energetici SpA or “GSE”). Energy generation revenue is recognized as the electricity generated by the Casalino and Campopiano assets is delivered to GSE. Revenues are based on actual output and “on-the-spot” predetermined prices for small renewable energy producers.

In addition to sales of renewable natural gas, we expect to generate a significant portion of our future revenue from the sale of conventional natural gas.

Expenses

General and Administrative (G&A) Expense

G&A expenses consist of compensation costs for personnel in executive, finance, accounting, and other administrative functions. G&A expenses also include legal fees, professional fees paid for accounting, auditing and consulting services, and insurance costs. As a newly public company, we expect that we will incur higher G&A expenses for public company costs such as compliance with the regulations of the Securities and Exchange Commission (the “SEC”) and the Nasdaq Capital Market.

Business Combination transaction expenses

Business Combination transaction expenses represent legal, consulting, advisory, accounting and other transaction fees and expenses related to the Business Combination, accounted for as a common control reverse recapitalization, that were expensed in connection with the Business Combination. A portion of the total costs incurred were recorded as a reduction in additional paid-in capital, up to the $0.6 million of proceeds received from the Trust, with costs in excess of funds raised from the Business Combination required to be expensed under GAAP. Management separated these expenses on its audited consolidated statement of operations for the year ended December 31, 2024 due to the significant and discrete nature of the expenses.

Income Tax Effects

AleAnna’s income tax consequences have been reflected in its consolidated financial statements in accordance with ASC 740, Income Taxes. Given AleAnna’s history of losses, and because future production remains uncertain, a full valuation allowance was applied against deferred tax assets as of December 31, 2024 and December 31, 2023, and no income tax liabilities or expenses were recognized as of or for the years ended December 31, 2024 or 2023.

We are also subject to a Valued-Added Tax (“VAT”) which is a broadly-based consumption tax that is assessed to the value that is added to goods and services. The VAT applies to nearly all goods and services that are bought and sold within the EU. Italian law allows for certain VAT payments to be recovered through ongoing applications for refunds. We have incurred higher VAT input paid (i.e., VAT paid on purchases) than the VAT output collected (i.e., VAT collected on sales), resulting in a net VAT refund receivable. As of December 31, 2024 and 2023, we had VAT receivables of $6.6 million, and $4.4 million, respectively.

Operations

Our net losses were $12.4 million and $5.2 million for the years ended December 31, 2024 and 2023, respectively. As of December 31, 2024 and December 31, 2023, we had an accumulated deficit of $191.0 million and $146.4 million, respectively. The majority of these losses stem from costs associated with the Longanesi field drilling and development, including asset impairments from previous years, as well as seismic imaging, exploratory costs for other conventional natural gas prospects, and general and administrative expenses. The accumulated deficits also include historical deemed dividends to the redemption value of AleAnna Energy’s previous Class 1 Preferred Units (exchanged for Class A and Class C common stock in connection with the Business Combination) based on the redemption features of those units and the related accounting requirements. See “Note 10 — Equity” to the audited condensed consolidated financial statements for further details. We expect to continue to incur substantial expenses related to our operations,

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exploration, and development activities, including pre-commercialization efforts as we continue our development of, and seek regulatory approval for, our discoveries and exploration prospects. Since inception, we have incurred net losses annually and do not expect to achieve sustained profitability until 2025. These shares were all exchanged for Class A and Class C common stock in connection with the Business Combination.

Results of Operations

Comparison of the year ended December 31, 2024 and 2023:

|  | For the Year Ended December 31, |  | Dollar Change |  | Percentage Change
|  | 2024 |  | 2023 |
Revenues |  | $ | 1,420,030 |  |  | $ | — |  |  | $ | 1,420,030 |  |  | NM |
Operating Expenses: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Cost of revenues |  | $ | 1,043,174 |  |  | $ | — |  |  | $ | 1,043,174 |  |  | NM |
General and administrative |  |  | 6,264,087 |  |  |  | 5,634,150 |  |  |  | 629,937 |  |  | 11 | %
Depreciation |  |  | 133,516 |  |  |  | — |  |  |  | 133,516 |  |  | NM |
Accretion of asset retirement obligation |  |  | 133,239 |  |  |  | 133,239 |  |  |  | — |  |  | 0 | %
Business Combination transaction expenses |  |  | 8,398,653 |  |  |  | — |  |  |  | 8,398,653 |  |  | NM |
Total Operating Expenses |  |  | 15,972,669 |  |  |  | 5,767,389 |  |  |  | 10,205,280 |  |  | 177 | %
Other Income (Expense): |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Interest and other income (expense) |  |  | 1,948,281 |  |  |  | (102,041 | ) |  |  | 2,050,322 |  |  | 2009 | %
Change in fair value of derivative liability |  |  | 173,177 |  |  |  | 708,869 |  |  |  | (535,692 | ) |  | -76 | %
Total Other Income (Expense) |  |  | 2,121,458 |  |  |  | 606,828 |  |  |  | 1,514,630 |  |  | 250 | %
Net loss |  | $ | (12,431,181 | ) |  | $ | (5,160,561 | ) |  | $ | (7,270,620 | ) |  | 141 | %
Deemed dividend to Class 1 Preferred Units redemption value |  |  | (155,423,177 | ) |  |  | (53,219,200 | ) |  |  | (102,203,977 | ) |  | 192 | %
Noncontrolling interests in earnings of subsidiaries |  |  | 87,511 |  |  |  | — |  |  |  | 87,511 |  |  | NM |
Net loss attributable to Class A Common stockholders or holders of Common Member Units |  | $ | (167,766,847 | ) |  | $ | (58,379,761 | ) |  | $ | (109,387,086 | ) |  | 187 | %
Other Comprehensive Income (Loss) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Currency translation adjustment |  |  | (1,548,154 | ) |  |  | 218,908 |  |  |  | (1,767,062 | ) |  | 807 | %
Comprehensive Loss |  | $ | (13,979,335 | ) |  | $ | (4,941,653 | ) |  | $ | (9,037,682 | ) |  | 183 | %

Revenues

During the year ended December 31, 2024, all of our revenue was earned through electricity generation and sales at the Casalino and Campopiano renewable natural gas plants that were purchased in July 2024. Cost of revenues consists of feedstock costs, direct labor and overhead necessary to produce RNG and generate electricity. All cost of revenues was related to the RNG assets that were purchased in 2024. See “Critical Accounting Policies and Estimates” for further details of our revenue recognition accounting policies.

General and Administrative (G&A) Expenses

General and administrative expenses consist of salaries and benefits, outside professional services including legal, human resources, audit and accounting services, and development stage expenses. We expect to continue to incur expenses to support operations as a public company, including expenses related to existing and future compliance with rules and regulations of the SEC and the Nasdaq, insurance expenses, investor relations, audit fees, professional services and general overhead and administrative costs.

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General and administrative expenses (exclusive of Business Combination transaction expenses) increased by $0.6 million, or 11%, for the year ended December 31, 2024, compared to the year ended December 31, 2023. The increase was primarily due to increases in legal, audit and consulting fees.

Business Combination transaction expenses

See “Expenses” above for a description of the Business Combination transaction expenses. These expenses were specific to the Business Combination that closed on December 13, 2024, with no similar expenses incurred in 2023.

Contingent Consideration Liability

As of December 31, 2024 and December 31, 2023, the contingent consideration liability was recorded at $25.0 million and $26.5 million, respectively. The estimate of the contingent consideration liability was determined based on inputs including the following as of December 31, 2024 and December 31, 2023: the intercontinental exchange futures prices for European natural gas, Euro to USD exchange rates of 1.04 and 1.11, respectively, and management’s future expected annual Longanesi production. We are required to make formulaic deferred consideration payments effectively equating to 20% to 50% of revenue above certain European natural gas threshold prices. The calculation and timing of such payments are primarily driven by future expected Longanesi production, as modeled by DeGolyer, as well as forward European natural gas prices. While the timing and quantities of expected Longanesi production were unchanged from December 31, 2023 to December 31, 2024, and we had fully accrued the total capped Euro amount of the liability, average annual European natural gas forward prices declined slightly.

Since the total capped Euro-denominated liability was recorded as of December 31, 2024, December 31, 2023, and December 31, 2022, any changes in the USD-equivalent amount were entirely due to foreign exchange rate fluctuations. As such, these changes were included in currency translation adjustment for the years ended 2024 and 2023.

Interest and Other Income (Expenses)

Interest and other income (expenses) primarily includes interest earned on cash and cash equivalents. Interest and other income increased by $2.1 million during the year ended December 31, 2024 compared to the same period in 2023, primarily due to interest earned on larger average cash balances during the 2024 period compared to the 2023 period presented. The larger cash balances were a result of the previously mentioned capital contributions in January and May of 2024. In 2023, the activity primarily related to lease operating expenses with minimal interest earned on lower cash and cash equivalents balances.

Change in Fair Value of Derivative Liability

The change in the fair value of derivative liability related to the Class 1 Preferred Units was $0.2 million during the year ended December 31, 2024, compared to $0.7 million during the same period in 2023. The fair value gain recorded during the year ended December 31, 2024 (representing a decrease in the liability) was primarily due to a higher liquidation threshold which was driven by capital contributions made during the first quarter of 2024 through the Class 1 Preferred Units. Part of the change was also driven by a lower estimated business value as of September 30, 2024 compared to December 31, 2023 due to a decline in forward natural gas prices. The derivative liability was reduced from $0.2 million as of December 31, 2023 to zero as of September 30, 2024 and was ultimately derecognized in conjunction with the Business Combination.

Currency Translation Adjustment

For the purposes of presenting consolidated financial statements, the assets and liabilities of our Euro operations are translated to USD at the exchange rate on the reporting date. The income and expenses are translated using average exchange rates. Foreign currency differences that arise on translation for consolidated purposes are recognized as a currency translation adjustment in other comprehensive loss on the consolidated statements of operations and comprehensive loss.

The currency translation adjustment decreased by $1.8 million for the year ended December 31, 2024 compared to the same period in 2023. This decrease was due to the fluctuation of the exchange rates between the Euro and the U.S. Dollar as well as the level of our activities.

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Segment Considerations

Our operations consist of one reportable segment reflecting the manner in which operations are managed and the criteria used by the chief operating decision maker (“CODM”), our Executive Chairman and Chief Executive Officer, collectively, to evaluate performance, develop strategy, and allocate resources.

AleAnna’s principal products include conventional natural gas produced from onshore exploration and development, and electricity and RNG derived from animal and agricultural waste. As of December 31, 2024, we had not yet generated revenue from our conventional natural gas activities and had only recently begun deriving revenue from sales of electricity related to our RNG business.

While we have recently acquired three RNG assets, these assets are still in the early stages of development which may include expansion and installation of upgrading units to refine biomethane into renewable natural gas (rather than conversion to electricity). These assets have not generated significant revenues or incurred material expenses. As of and for the year ended December 31, 2024, the CODM was primarily focused on capital investing decisions, strategy, and forward-looking investment economics. While the CODM monitors cash reserves and overall enterprise liquidity, extensive review and analysis of the our performance and loss statements is not performed beyond review of the consolidated financial statements. As such, the CODM continues to assess our financial performance as a single enterprise on a consolidated basis, without distinguishing between conventional natural gas and RNG operations. Given we have not generated significant revenue or profits and are focused on development activities, the CODM does not utilize a specific measure of profit or loss to assess performance. The CODM does not monitor specific expense categories separately. The financial information reviewed by the CODM is consistent with the audited consolidated balance sheets and statements of operations and cash flows included herein.

All of the Company’s primary operating activities and assets remain located in Italy. We will continue to assess the need for including multiple reportable segments as the business evolves.

Liquidity, Capital Resources and Operations

We have generated minimal revenues from our operations to date and we had an accumulated deficit of $191.0 million as of December 31, 2024. We had $28.3 million in cash and cash equivalents on December 31, 2024. The Company’s continuing operations, as intended, are dependent upon its ability to generate cash flows or obtain additional financing. Between January 2024 and May 2024, prior to the Business Combination, we received an aggregate of $62.1 million in capital contributions from AleAnna Energy members resulting in the issuance of 62,100 Class 1 Preferred Units, to fund operating costs, capital expenditures, Business Combination related transaction expenses, and to and provide working capital to meet our liabilities and commitments as they become due. In addition, we are exploring Resource Backed Loan (“RBL”) financing and renewable natural gas project loan products with several financial institutions; however, there is no guarantee that such financing will be available to us. As a normal part of our business, depending on market conditions, we may from time to time consider opportunities to repay, redeem, repurchase or refinance the indebtedness of our subsidiaries or issue equity securities to raise additional capital. Changes in our operating plans, lower than anticipated revenues, increased expenses, acquisitions or other events may cause us to seek additional debt or equity financing in future periods. There can be no guarantee that financing will be available on acceptable terms or at all.

Presently, Padana is the operator of the Longanesi field under a Unitized Operating Agreement, and other companies in the future may operate some of the properties in which we have an interest. The failure of an operator of our wells or joint venture participant to adequately perform operations, an operator’s breach of the applicable agreements or an operator’s failure to act in ways that are in our best interest could reduce our production and revenues.

To mitigate operator risks, we monitor the operational risks, credit risk, financial position and liquidity of Padana. Operational risks are monitored and acted on through: (i) periodic meetings with Padana, through a formal committee known as the “Technical Committee”, to examine upcoming activities and discuss questions and concerns, (ii) through the receipt and analysis of daily reports, (iii) through requesting unscheduled calls with Padana where areas of concern are identified, and (iv) through occasional site visits. Further, Padana’s credit risk, financial position, and liquidity are periodically evaluated through review of the financial condition of Padana’s parent organization, Gas Plus S.p.A., which is a publicly-traded company on the Italian Stock Exchange (Euronext Milan). We are able to continuously monitor financial health of Gas Plus S.p.A. through exchange-required public disclosures, including half-annual and annual financial statements, corporate presentations, and press releases.

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Cash Flows

The following table includes our cash flow data for the years ended December 31, 2024 and 2023:

|  | For the Year Ended December 31,
|  | 2024 |  | 2023
Consolidated Statement of Cash Flows Data: |  |  |  |  |  |
Net cash used in operating activities |  | (16,897,557 | ) |  | (5,749,303 | )
Net cash used in investing activities |  | (23,066,287 | ) |  | (8,924,941 | )
Net cash provided by financing activities |  | 62,106,468 |  |  | 21,004,132 |

Cash used in operating activities

Cash used in operating activities increased by $11.1 million for the year ended December 31, 2024, compared to the year ended December 31, 2023. Overall, increases in cash used in operating activities reflect increased operating expenditures primarily related to legal, consulting and audit fees and salaries and wage expenses, in addition to the Business Combination transaction expenses.

Cash used in investing activities

Cash used in investing activities increased by $14.1 million for the year ended December 31, 2024, compared to the year ended December 31, 2023.

In all periods presented, cash used in investing includes continued drilling, completion, and tie in of Longanesi-2D and Longanesi-3D wells. In year ended December 31, 2024, cash used in investing activities also reflects approximately $9.5 million of cash used to purchase three separate renewable natural gas assets, and approximately $5.1 million paid to Blugas as part of the Blugas Settlement (exclusive of VAT). These transactions are discussed in more detail in the Recent Developments section.

Cash provided by financing activities

Cash provided by financing activities in all periods presented reflects pre-Business Combination issuances of AleAnna Energy Class 1 Preferred Units used to fund our operations. Such Class 1 Preferred Units were exchanged for Class A and Class C commons stock as part of the Business Combination. The cash proceeds from the Business Combination, net of expenses allowed to be capitalized, had a negligible impact on financing cash flows as the majority of the Business Combination transaction expenses were required to be expensed and were included in net loss within operating cash flows.

Contractual Obligations and Other Commitments

Participation Agreements and Blugas ORRI

In the normal course of business, we enter into agreements with other entities to assist in the performance of drilling of the Longanesi field. On June 26, 2009, we entered into a Participation Agreement with Padana for the drilling of the ‘Longanesi 1 exploration well, ‘San Potito’ concession and ‘Abbadessee 1’ exploration,’ collectively referred to as the Longanesi field.

The Unified Operating Agreement arrangement was originally signed between Eni and Grove and dated September 26, 2009. However, Padana has succeeded Eni as the operator and 66.5% working interest owner, and we succeeded Grove as the non-operator and 33.5% working interest owner. On July 13, 2016, we acquired a 33.5% working interest in the Longanesi field from Enel, and, as part of the purchase, acquired a legacy contingent liability arising from an agreement between the Longanesi working interest’s original owner Grove Energy and Blugas. Blugas retained an interest akin to an ORRI, whereby Blugas was entitled to physical delivery of 20% of the first 350 million standard cubic meters (approximately 2,472 106ft3) produced from the Longanesi field. Prior to the Blugas settlement in May 2024 (as further described below), in accounting for the acquisition of the 33.5% working interest, we did not recognize an asset or liability in the consolidated financial statements related to the Blugas ORRI as our SEC Case

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reserves estimates contemplated the contractual arrangement and physical gas delivery to Blugas, such that the gas revenues attributable to our 33.5% working interest were reduced to reflect sale of the Blugas quantity and payment of such revenues (cash outflows to Blugas).

The physical volumes due to Blugas were being contested by us as usury because we considered, among other reasons, that extraction services and all associated risks are executed by us and that participation by Blugas was limited to financing a part of the sum necessary to start drilling, without participation in the construction and exploitation of the reservoir, and therefore do not share the risks or costs, which had increased compared to the initial forecast of the investment.

On May 28, 2024, we entered into the Blugas Settlement Agreement regarding the Blugas ORRI whereby Blugas was entitled to physical delivery of 20% of the first 350 million standard cubic meters (approximately 2,472 106ft3) produced from the Longanesi field. Under the terms of the Blugas Settlement Agreement, we paid Blugas approximately €5 million, plus an additional €1.1 million in applicable VAT, or a total of approximately $6.6 million. In exchange, we were released from any future liability related to the Blugas ORRI. As a result of the transactions contemplated by the Blugas Settlement Agreement, our 33.5% working interest in the Longanesi field is now unencumbered except for normal government royalties (10%). The Blugas Settlement Agreement was accounted for as an acquisition of the Blugas ORRI claim with a corresponding increase to the expected future cash flows from our reserves. Our year-end December 31, 2023 reserve quantities included the 20% of 350 million standard cubic meters (approximately 2,472 106ft3) allocable to the Blugas ORRI in our proved gas reserves. However, the required payments to Blugas associated with the sale of such quantities were reflected as cash outflows (costs) in our year-end December 31, 2023 reserve report as if such amounts were paid to Blugas. Following settlement, our year-end December 31, 2024 reserve quantities continue to include the 20% of 350 million standard cubic meters (approximately 2,472 106ft3), however, the previously required payments to Blugas associated with the sale of such quantities are no longer reflected as cash outflows (costs) as if such amounts were paid to Blugas. As the cash outflows (costs) are no longer reflected as if paid to Blugas, such amounts are reflected in our December 31, 2024 reserve report as allocable to our unencumbered 33.5% working interest.

Contingent Consideration Liability

In connection with our purchase of our 33.5% working interest in the Longanesi field, consideration paid included €7 million cash and up to €24 million of deferred consideration payable upon production of the Longanesi field. The deferred consideration is payable based on a formulaic calculation which is predominantly dependent on sales volumes and spot natural gas prices during the first 12 years of production (the “Earn-Out Period”). There will be no deferred consideration due if Longanesi is not developed and no deferred consideration due if average annual gas prices are less than €3.65/Mcf over the Earn-Out Period. Upon first production, AleAnna will also be required to reserve cash collateral of €3 million related to the contingent consideration liability which will be classified as restricted cash in future balance sheets and may be used to satisfy the contingent consideration liability as payments become due.

We recognized a liability for the contingent consideration in accounting for the asset acquisition in accordance with ASC 450, Contingencies (“contingent consideration liability”). As of December 31, 2024, and December 31, 2023, the total contingent consideration liability was recorded at $25.0 million and $26.5 million, respectively.

Internal Control over Financial Reporting

Effective internal controls are necessary to provide reliable financial reports and prevent fraud. AleAnna is a newly public company that is in the process of adding resources with the appropriate level of experience and technical expertise to oversee AleAnna’s business processes and controls. At this time, AleAnna does not have the necessary business processes and related internal controls formally designed and implemented.

As a result, AleAnna previously identified material weaknesses in its internal control over financial reporting. A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting such that there is a reasonable possibility that a material misstatement of annual or interim financial statements would not be prevented or detected on a timely basis.

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In connection with the preparation of AleAnna’s financial statements as of and for the years ended December 31, 2024 and 2023, management of AleAnna identified material weaknesses in its internal control over financial reporting as follows:

• Management did not maintain an effective control environment in accordance with the COSO framework as it did not maintain a sufficient complement of accounting and reporting resources commensurate with its financial reporting requirements. This material weakness contributed to the following material weaknesses:

• Management did not design, implement, and operate controls over the selection and implementation of accounting policies to ensure amounts recorded and disclosed were fairly stated in accordance with GAAP.

• Management did not design or maintain appropriate account reconciliation and journal entry review controls to review the work of third-party consultants used to assist management in recording transactions.

We are in the early stages of designing and implementing a plan to remediate the material weaknesses identified. Our plan includes the below:

• Designing and implementing a risk assessment process supporting the identification of risks facing AleAnna.

• Implementing controls to enhance our review of significant accounting transactions and other new technical accounting and financial reporting issues and preparing and reviewing accounting memoranda addressing these issues.

• Hiring additional experienced accounting, financial reporting and internal control personnel and changing roles and responsibilities of our personnel as we transition to being a public company and are required to comply with Section 404 of the Sarbanes-Oxley Act.

• Implementing controls to enable an accurate and timely review of accounting records that support our accounting processes and maintain documents for internal accounting reviews.

The Company cannot assure you that these measures will remediate the material weaknesses described above. The implementation of these remediation measures is in the early stages and will require validation and testing of the design and operating effectiveness of the Company’s internal controls over a sustained period of financial reporting cycles and, as a result, the timing of when the Company will be able to remediate the material weaknesses is uncertain and the Company may not remediate these material weaknesses during the year ended December 31, 2024. If the steps the Company takes do not remediate the material weaknesses in a timely manner, there could be a reasonable possibility that these control deficiencies or others may result in a material misstatement of its annual or interim financial statements that would not be prevented or detected on a timely basis. This, in turn, could jeopardize the Company’s ability to comply with its reporting obligations, limit its ability to access the capital markets and adversely impact its stock price.

Emerging Growth Company Accounting Election

Section 102(b)(1) of the JOBS Act exempts emerging growth companies from being required to comply with new or revised financial accounting standards until private companies are required to comply with the new or revised financial accounting standards. The JOBS Act provides that a company can elect not to take advantage of the extended transition period and comply with the requirements that apply to non-emerging growth companies, and any such election to not take advantage of the extended transition period is irrevocable. We expect to be an emerging growth company at least through 2025.

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Critical Accounting Policies and Estimates

Our unaudited consolidated financial statements are based on the selection and application of significant accounting policies. The preparation of our management’s discussion and analysis of our financial condition and results of operations is based on our audited consolidated financial statements as of and for the years ended December 31, 2024 and 2023, which have been prepared in accordance with GAAP. In preparing these financial statements, we make estimates and assumptions impacting asset and liability amounts, disclosure of contingent liabilities, and expenses incurred.

The estimates are based on our historical experience and on various other factors that we believe are reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. We regularly assess these estimates; however, actual amounts could differ materially from those estimates under different assumptions or conditions. The most significant items involving management’s estimates include estimates of contingencies including the contingent consideration liability discussed below. The impact of changes in estimates is recorded in the period in which they become known.

The accounting policies discussed below are critical to understanding our historical and future performance, as these policies relate to the more significant areas involving management’s judgments and estimates.

Conventional Natural Gas Properties

We use the successful efforts method of accounting for conventional gas-producing activities. Under this method, the cost of productive wells and related equipment, development dry holes, and any permits related to productive acreage are capitalized, and depleted using the unit-of-production method. These costs include other internal costs directly attributable to production activities. We are not yet recognizing depletion as assets are not yet producing and therefore have not yet been placed in service. Costs for exploratory dry holes, exploratory geological and geophysical activities, and delay rentals as well as other property carrying costs are charged to exploration expense.

There were no exploratory wells drilled or capitalized exploratory well costs in the years ended 2024 or 2023. All asset additions in the years ended 2024 and 2023, relate to the drilling of three Longanesi development wells. Such wells began production in March 2025.

Proved gas reserves, are those quantities of gas that, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward from known reservoirs and under existing economic conditions, operating methods and government regulations prior to the time at which contracts providing the right to operate expire unless evidence indicates that renewal is reasonably certain regardless of whether deterministic or probabilistic methods are used for the estimation.

The estimates of proved natural gas reserves (“SEC Case”) utilized in the preparation of our consolidated financial statements are estimated in accordance with the rules established by the SEC and the Financial Accounting Standards Board (“FASB”). These rules require that reserve estimates be prepared under existing economic and operating conditions using a trailing 12-month average price with no provision for price and cost escalations in future years except by contractual arrangements. The development of our natural gas reserve quantities requires management to make significant estimates and assumptions related to the intent and ability to complete undeveloped proved reserves within a five-year development period, as prescribed by SEC guidelines. Management engaged DeGolyer to prepare reserves estimates for our estimated proved reserves at December 31, 2024, and 2023. The technologies used in the estimation of our net proved undeveloped reserves include, but are not limited to, empirical evidence through drilling results and well performance, production data, decline curve analysis, well logs, geologic maps, core data, seismic data, demonstrated relationship between geologic parameters and performance, and the implementation and application of statistical analysis.

Management has confirmed that none of the Unitized Operating Agreement’s reserves nor the Proved Undeveloped Reserves (“PUDs”) are scheduled to be developed on a date more than five years from the date the reserves were initially recognized as PUDs as prescribed by SEC guidelines. PUDs are converted from undeveloped to developed as applicable wells begin production.

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Reserve estimates are inherently imprecise. Accordingly, the estimates are expected to change as more current information becomes available. Such estimates are subject to the uncertainties inherent in the application of judgmental factors in interpreting such information. It is possible that, because of changes in market conditions or the inherent imprecision of reserve estimates, the estimates of future cash inflows, future gross revenues, the volume of natural gas reserves, the remaining estimated lives of natural gas properties, or any combination of the above may be increased or decreased. Increases in recoverable economic volumes generally reduce per-unit depletion rates, while decreases in recoverable economic volumes generally increase per-unit depletion rates.

Revenue Recognition

General — We follow the guidance of FASB Accounting Standards Codification 606, Revenue from Contracts with Customers (“ASC 606”). The core principle underlying revenue recognition under ASC 606 is that revenue should be recognized as goods or services are transferred to customers in an amount that reflects the consideration to which we expect to be entitled. ASC 606 defines a five-step process to achieve recognition and mandates additional disclosure about the nature, amount, timing and uncertainty of revenues and cash flows arising from customer contracts, including significant judgments, and changes in judgments and assets recognized from costs incurred to obtain or fulfill a contract.

Renewable Natural Gas — As of December 31, 2024, we primarily earn revenue through electricity generation revenue from the conversion of bio feedstocks to biomethane which is then converted to electricity through reciprocating generators. Such electricity is then delivered onto the grid through a metered interconnection and sold to the local state-owned electrical utility responsible for the purchase and marketing of energy produced by small-scale renewable energy assets. Upon delivery of the electricity to the grid, all performance obligations have been satisfied and energy generation revenue is recognized based on actual output and non-company specific predetermined prices for small renewable energy producers of €280/MWh established under Ministerial Decree (D.M.) 18/12/ December 2008), which sets tariff rates for small renewable energy producers in Italy.

Revenue is recognized over time as we transfer the electricity to the grid at a metered interconnection. The customer obtains control of the product upon delivery onto the electrical grid. We generally have a single performance obligation in our arrangements with our customers. We have no long-term contracts containing quantity or electricity volume production requirements and there is no variable consideration present in our performance obligations. Per ASC 606-10-25-27(a), delivery of units of power that are simultaneously received and consumed by the customer would satisfy the criteria to be accounted for as a performance obligation satisfied over time and the same method would be used to measure the entity’s progress towards complete satisfaction of the performance obligation to transfer each distinct unit of power in the series to the customer. Our performance obligation related to the sales of electricity are satisfied over time upon delivery to the customer. Revenue is measured as the amount of consideration we expect to receive in exchange for transferring our products. We apply a practical expedient in FASB ASC 606-10-55-18 applicable to our sales by assessing whether our right to consideration corresponds directly with the value to our customers (the “invoice practical expedient”). We concluded that pricing corresponds to the value provided to the customer. Consideration for each transaction is based upon non-company specific predetermined prices for small renewable energy producers of €280/MWh, established under Ministerial Decree (D.M.) 18/12/December 2008), which sets tarrif rates for small renewable energy producers in Italy. Payment terms are typically two months after the invoice date and there are no return or refund rights.

Business Combinations and Asset Acquisitions

We evaluate whether a transaction meets the definition of a business. We first apply a screen test to determine if substantially all of the fair value of the gross assets acquired is concentrated in a single identifiable asset or group of similar identifiable assets. If the screen test is met, the transaction is accounted for as an asset acquisition. If the screen test is not met, we further consider whether the set of assets acquired have, at a minimum, inputs and processes that have the ability to create outputs in the form of revenue. If the assets acquired meet this criteria, the transaction is accounted for as a business combination.

Acquisitions that qualify as an asset acquisition are accounted for using a cost accumulation model where the purchase price of the acquisition is allocated to the assets acquired on a relative fair value basis on the date of acquisition. We generally account for acquisitions of renewable natural gas assets as asset acquisitions. Inputs used to determine such fair values are primarily based upon internally-developed estimates, estimates developed by third-party

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valuation firms, and publicly-available data regarding renewable natural gas asset transactions consummated by other buyers and sellers, as applicable. These fair values are considered Level 3 assets in the fair value hierarchy. Any associated acquisition costs are generally capitalized.

Acquisitions that qualify as a business combination are accounted for using the acquisition method of accounting. The fair value of consideration transferred for an acquisition is allocated to the assets acquired and liabilities assumed based on their fair value on a nonrecurring basis on the acquisition date and are subject to fair value adjustments under certain circumstances. The excess of the consideration transferred over the fair value of assets acquired and liabilities assumed is recorded as goodwill. Conversely, in the event the fair value of assets acquired and liabilities assumed is greater than the consideration transferred, a bargain purchase gain is recognized.

Determining the fair value of assets acquired and liabilities assumed requires judgment and often involves the use of significant estimates and assumptions as fair values are not always readily determinable. Different techniques may be used to determine fair values, including market prices (where available), comparisons to transactions for similar assets and liabilities and the discounted net present value of estimated future cash flows, among others. We engage third-party valuation firms when appropriate to assist in the fair value determination of assets acquired and liabilities assumed. Acquisition-related expenses and transaction costs associated with business combinations are expensed as incurred. We may adjust the amounts recognized in an acquisition during a measurement period not to exceed one year from the date of acquisition, as a result of subsequently obtaining additional information that existed at the acquisition date.

Where applicable, asset acquisitions may be owned together with unaffiliated outside parties. In acquisitions where we have a majority direct controlling interest, the unaffiliated outside ownership is shown as noncontrolling interests in members’ equity in our consolidated financial statements.

Contingent Consideration Liability

On July 13, 2016, AleAnna Europa S.r.l., a former subsidiary of AleAnna Resources LLC (which was subsequently merged into AleAnna Italia S.p.A. in December 2022), purchased a 33.5% working interest in the Longanesi field, which was accounted for as an asset acquisition. Consideration paid included €7 million cash and up to €24 million of deferred consideration payable upon production of the Longanesi field. The deferred consideration is payable based on a formulaic calculation which is predominantly dependent on sales volumes and spot natural gas prices during the first 12 years of the Earn-Out Period. There will be no deferred consideration due if Longanesi is not developed and no deferred consideration due if average annual gas prices are less than €3.65/Mcf over the Earn-Out Period.

We recognized a liability for the contingent consideration in accounting for the asset acquisition in accordance with ASC 450, Contingencies (the “contingent consideration liability”) based on our assessment of probability of the occurrence of payment and deemed the liability estimable based on the formulaic nature. See Note 3 for more information.

Income Taxes

The Company follows the asset and liability method of accounting for income taxes under ASC 740, “Income Taxes.” Deferred tax assets and liabilities are recognized for the estimated future tax consequences attributable to differences between the consolidated financial statements carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that included the enactment date. Valuation allowances are established, when necessary, to reduce deferred tax assets to the amount expected to be realized.

ASC 740 prescribes a recognition threshold and a measurement attribute for the financial statement recognition and measurement of tax positions taken or expected to be taken in a tax return. For those benefits to be recognized, a tax position must be more likely than not to be sustained upon examination by taxing authorities. The Company recognizes accrued interest and penalties related to unrecognized tax benefits as income tax expense. There were no unrecognized tax benefits and no amounts accrued for interest and penalties as of December 31, 2024 or 2023. The Company is currently not aware of any issues under review that could result in significant payments, accruals or material deviation from its position. The Company is subject to income tax examinations by major taxing authorities since inception.

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Asset Retirement Obligation

We recognize a liability for asset retirement obligations (“AROs”) based on an estimate of the amount and timing of settlement at the time a legal obligation is incurred. Upon initial recognition of an ARO, we increase the carrying amount of the long-lived asset by the same amount as the liability. The initial capitalized costs will be depleted over the useful (productive) lives of the related assets.

Our asset retirement obligations relate to the abandonment of gas production facilities including reclaiming well pads, reclaiming water impoundments, plugging wells and dismantling related structures. Estimates are based on historical experience of plugging and abandoning wells and reclaiming of disposing other assets and estimated remaining (productive) lives of the wells and assets.

No incremental ARO liabilities were incurred during the year ended December 31, 2024. During the year ended December 31, 2023, we incurred incremental ARO liabilities, for one new development area associated with Longanesi (Casale Cocchi 1). Otherwise, changes in ARO between periods presented only relate to the accretion of the liability. We do not have any assets that are legally restricted for purposes of settling these obligations.

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BUSINESS

The following discussion reflects the business of AleAnna both prior to and after giving effect to the Business Combination, as the context indicates. Unless the context otherwise requires, all references in this section to “AleAnna,” the “Company,” “we,” “us,” and “our,” refer to AleAnna, Inc. and its consolidated subsidiaries.

Overview

AleAnna is a development-stage natural gas resource company focused on delivering critical natural gas supplies to Europe through both onshore conventional natural gas exploration and development and renewable natural gas development in Italy. We have several conventional natural gas discoveries including the Longanesi field, located in the Po Valley in Northern Italy, which is one of Italy’s largest modern natural gas discoveries. We have a 33.5% working interest in the Longanesi field with our working interest partner, and operator, Padana. We acquired our working interest in the Longanesi field in 2016. We also retain wholly-owned concessions, permits, and pending applications on other exploration and development prospects across Italy which are supported by proprietary modern 3D seismic reservoir imaging. In 2021, we launched a renewable natural gas development business focused on bringing to market carbon negative renewable natural gas derived from animal and agricultural waste. Between March 2024 and July 2024, we successfully completed three separate strategic acquisitions of renewable natural gas plant projects in Italy for an aggregate €9,087,882, or approximately $9,829,034. The plants are fully permitted and are in various stages of the production lifecycle, with one greenfield plant that is a new development and two brownfield plants that are currently operational. We plan to develop and upgrade these sites for renewable natural gas production in the future. We expect to begin construction on our Camapagnatico greenfield facility in 2025 and that Campagnatico has been preliminarily approved for government-backed incentives for both capital expenditure reimbursement and a biomethane floor price through the end of 2039 of €124 per MWh, equivalent, as of December 31, 2024, to $37.60 per 103ft3. Such incentives are subject to successful completion and start-up of the Campagnatico facility. As a development-stage company, while we have generated electricity revenue from our RNG plants, we had not yet generated any revenue from our principal business activities as of December 31, 2024.

Over the past 15 years, we have invested approximately $227 million in the acquisition and initial development of our properties, and we own a portfolio of conventional natural gas properties, including Longanesi, Gradizza, and Trava, containing approximately 17.6 (109ft3) net recoverable proved undeveloped natural gas reserves according to our independent third-party reserve engineer, DeGolyer. Beyond our net recoverable natural gas reserves, we have 13 development prospects at various stages of permitting, supported by 3D seismic surveys, and leases on approximately 2.7 million net acres — paving the way for future exploration and development. Our recent activities involve the drilling and testing of three Longanesi development wells (2022 and 2023) as well as the completion of two original discovery wells. Tie-in of these wells is complete, and we are currently executing the installation of a temporary processing facility. We and Padana achieved first production of the five wells in the Longanesi field in March 2025 through use of a temporary processing facility. The permanent processing facility is expected to be constructed over the course of 2025 and early 2026 and commissioned in mid-2026. On October 29, 2024, we entered into a gas sale agreement (“GSA”) with Shell Energy Europe Limited (“SEEL”), whereby SEEL became the exclusive buyer of our share of the natural gas produced from the Longanesi field net of (i) any consumption and/or losses incurred in the transport, treatment and compression of gas before delivery; (ii) any volume to be allocated for regulated royalties auctions, if applicable; and (iii) any other volume contractually allocated to other parties before August 31, 2022. Future sales under the GSA are contingent upon the commencement of gas production. As of December 31, 2024, we have not derived revenue from its conventional natural gas business.

Additionally, our renewable gas team has built a substantial backlog of acquisition targets we believe are poised to support rapid growth in the Italian bio-methane market. With several conventional and renewable projects under development, expected to initially generate revenue in the next 18 to 24 months.

We expect to be able to fund our future growth primarily out of cash from operations from the Longanesi, Gradizza, and Trava developments and with cash on hand. We believe that the synergies of our conventional and renewable natural gas businesses will provide us the financial flexibility to shift capital deployment between the two businesses as the energy transition unfolds.

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We believe that our highly experienced and credentialed management team, consisting of former executives of Shell, Eni, and Exxon, provides the company access to a best-in-class technology platform, an excellent in-country business development network, strong collaboration with Italian regulators, and experience with local regulatory processes. Our senior management team has over 100 years of combined experience in the upstream conventional and renewable energy industries. We are managed by William (“Bill”) Dirks, our Executive Director, and Marco Brun, our Chief Executive Officer, under the direction of our Board.

AleAnna is headquartered in Dallas, Texas, and has offices in Rome, Italy.

Business Combination

On December 13, 2024, we consummated the previously announced business combination pursuant to the Merger Agreement, dated June 4, 2024, by and among Swiftmerge, HoldCo, Swiftmerge Merger Sub LLC, a Delaware limited liability company and wholly-owned subsidiary of HoldCo, and AleAnna Energy. Pursuant to the terms of the Merger Agreement, on December 13, 2024, SPAC migrated to and domesticated as a Delaware corporation in accordance with Section 388 of the Delaware General Corporation Law, as amended, and the Companies Act (As Revised) of the Cayman Islands and changed its name to AleAnna, Inc. The transactions contemplated by the Merger Agreement are collectively referred to herein as the “Business Combination.”

The Business Combination was accounted for as a common control transaction with respect to AleAnna Energy which is akin to a reverse recapitalization. This conclusion was based on the fact that Nautilus Resources LLC (“Nautilus”) had a controlling financial interest in AleAnna Energy prior to the Business Combination and has a controlling financial interest in AleAnna, which includes AleAnna Energy as a wholly owned subsidiary. The net assets of SPAC are stated at their historical carrying amounts with no goodwill or intangible assets recognized in accordance with the accounting principles generally accepted in the United States of America (“GAAP”). The Business Combination with respect to AleAnna Energy was not treated as a change in control primarily due to Nautilus receiving the controlling voting stake in AleAnna and the ability of Nautilus to nominate the full board of directors and management of AleAnna.

Under a reverse recapitalization, SPAC is treated as the “acquired” company for financial reporting purposes. Accordingly, for accounting purposes, the Business Combination is treated as the equivalent of AleAnna Energy issuing stock for the net assets of SPAC, accompanied by a recapitalization.

We incurred $9.5 million in transaction costs related to the Business Combination. Approximately $0.6 million of these costs were recorded as a reduction to additional paid-in capital, up to the amount of cash proceeds received in the transaction. Of the remaining $8.9 million, approximately $0.5 million represented prepaid directors and officers insurance premiums that were recorded to other assets in the consolidated balance sheet, and $8.4 million represented legal, accounting, consulting and advisory fees that were recorded as Business Combination transaction expenses in the consolidated statement of operations and comprehensive loss.

Our Business Strategies

Conventional Natural Gas Business

We intend to leverage the technical and operational expertise of our management team, particularly with including in the use of 3D seismic and Direct Hydrocarbon Indicators (“DHIs”), to achieve attractive success rates and growth of reserves, production and cash flow. We believe the following factors are key to achieving these goals:

• the use of industry-leading technologies and techniques to significantly increase the probability of drilling success;

• a robust natural gas price environment, with current takeaway prices of approximately $10-$15 per (103ft3), which are approximately 3-4 times the current Henry Hub spot price;

• geographically advantaged developments that are adjacent to a well-developed pipeline network containing large excess transport capacity;

• relatively low-cost, low-risk, onshore operations through which our natural gas can be brought to market at costs of approximately $1-3 per 103ft3;

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• short expected payout periods and high expected rates of return on developments, supported by high quality, high flow rate, reservoirs, and a low combined federal and regional royalty regime (10%);

• nimble operating model with a focus on utilizing outsourced resources to control costs; and

• proactive relationships with larger enterprises (like Shell and Eni Ecofuels (“Eni”)) to further our marketing and potential hedging strategies, and to support our ongoing conventional natural gas exploration and development aspirations.

Renewable Natural Gas Business

We intend to develop and grow our renewable natural gas business through the acquisition of operational Anaerobic Digesters (or “AD’s”) and their conversion to biomethane facilities. We believe the following factors are key to achieving this goal:

• existing AD’s (“Brownfield Facilities”) are cheaper to acquire and have a lower risk profile than new-build opportunities (“Greenfield Facilities” or “Greenfield”) and their conversion to biomethane is relatively efficient and can be accomplished within a short time frame through installation of an “off-the-shelf” biogas upgrading unit;

• we believe we have unique regional overlap across our conventional and renewable natural gas businesses as our conventional focus area, Italy’s Po Valley, contains the majority of the existing Italian AD’s and is adjacent to a comprehensive natural gas pipeline network operated by the Italian-sponsored SNAM, which exists in close proximity to our conventional business and the Po Valley AD’s;

• as one of a few licensed Italian Exploration & Production (“E&P”) operators, we believe we have the means, mechanisms, and market relationships to bring biomethane to market, whereas those tasks are above the capabilities of most family farms and farm association who currently own and operated existing AD’s;

• we believe the construction and operation of a biomethane facility is similar to the operation of a conventional natural gas facility, a capability which we already possess;

• by either including the family farm as a working-interest partner or entering into bespoke feedstock contracts, we believe we can enlist the farms’ support in creating necessary AD fuels and in the disposal of waste products from the AD (which are converted into fertilizer), without our business having to become proficient in farming;

• we believe that a combination of free cash flows from our conventional natural gas business, together with other cash on hand, and future project level debt financing will satisfy the near-term capital requirements of our renewable natural gas portfolio; and

• as discussed in more detail below, the Italian government’s 15-year guaranteed biomethane floor price of $39.30 per 103ft3 substantially mitigates pricing risk from the renewable natural gas business.

Natural Gas Demand

Although Italy has numerous hydrocarbon-producing basins with significant undeveloped oil and gas deposits, both onshore and offshore, in 2022 Italy imported 96% of its natural gas and has one of the highest concentrations of natural gas as a component of total energy use, at almost 40% by kilotons of oil equivalent. Its reliance on imports has led to a paradigm shift in the Italian political landscape towards securing domestic energy supply. In addition, Italy has in recent decades opened oil and gas exploration and development permits to the global E&P industry beyond the historical domain of Italy’s former National Oil Company (“NOC”), Eni.

Catering to this renewed emphasis on secure domestic energy supply, we are focused on exploitation and producing activities in the prolific and well-derisked Po Valley of northern Italy using modern proprietary 3D seismic surveys, which has led us to believe the Po Valley contains numerous opportunities to explore for and develop conventional natural gas fields. The Po Valley is ripe with access to a dense network of government-controlled natural gas pipelines that can transport our products to industrial, power generation and residential customers throughout Italy and into the southern EU. Additionally, according to Eurostat, Italy is second only to Germany in the EU in terms of the value of natural gas sold for industrial power and heat requirements, and the Po Valley is adjacent to Italy’s core, high-energy demand, manufacturing centers. Supporting the vital energy needs of this industrial production base,

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Po Valley reservoirs are largely high-quality, with unique properties that allow for the application of an important exploration and development technology known as DHIs, through which natural gas deposits can be “seen” on modern seismic surveys. We believe the use of DHI technology dramatically increases the probability of drilling success and lower development costs.

In addition, throughout the central and southern EU (but primarily focused in Italy and Germany), member states’ interest in creating new sources of renewable energy has supported the construction of nearly 10,000 AD’s over the past 15 years. Largely family-farm owned and operated and fueled by crop and livestock wastes, these AD’s are currently creating a meaningful, sustainable, supply of raw biogas (approximately 50% methane and 50% CO2 and other waste gases) according to the European Biogas Association, the precursor to pipeline-quality biomethane (99.5% pure methane). Virtually all existing AD’s were designed to burn raw biogas in highly inefficient reciprocating engines to produce electricity. However, the Italian government’s financial incentives and subsidies supporting these activities are set to be replaced by attractive biomethane capital and pricing incentives to stimulate conversion of these AD’s to the production of biomethane production. Such incentives are designed to bring biomethane into the national pipeline transmission system in order to deliver the natural gas to higher efficiency, utility-scale, natural gas power generation stations. In order to continue biogas operations, the farms are forced to seek a new use for the product, which will be dominated by conversion to biomethane. To support this conversion, Italy has implemented a government-backed biomethane floor price through the end of 2039 of €124 per MWh, equivalent, as of December 31, 2024 to $39.25 per 103ft3.

Our Operations

Conventional Natural Gas Business

We began studying Italian opportunities in 2007 and, over the last 15 years, have invested approximately $227 million to build a large asset base and exploration and development prospect inventory. Our portfolio is largely comprised of a group of three discoveries, one developed (Longanesi) and two currently awaiting regulatory approval (Gradizza, and Trava), surrounded by an additional 13 development and exploration prospects within the Longanesi and Ponte dei Grilli “Clusters” that are at various stages of permitting and are supported by proprietary 3D seismic surveys. According to our independent third-party reserve engineer, DeGolyer, these clusters contain approximately 17.6 (109ft3) of proved recoverable natural gas net to us primarily related to our working interest in the Longanesi field but do not include the additional development prospects we have identified and likely intend to drill in the near future.

In addition, our investments in approximately 140,000 acres (approximately 567 km2) of modern, high-quality, 3D seismic surveys in the eastern Po Valley underpin our conventional natural gas growth plan and many of our expected development and exploration prospects are in advanced stages of permitting. Our immediate focus is on the extension of the Longanesi Field together with Padana. We expect to drill two additional high-quality development wells by year end 2026, bringing the Longanesi field to a total of seven wells. In addition to the Longanesi expansion, we are simultaneously focused on 13 100% working interest exploration prospects that currently reside at various stages of permitting.

On October 29, 2024, we entered into a Gas Sales Agreement (“GSA”) with Shell Energy Europe Ltd (“SEEL”), whereby SEEL became the exclusive buyer of our share of the natural gas produced from the Longanesi field net of (i) any consumption and/or losses incurred in the transport, treatment and compression of gas before delivery; (ii) any volume to be allocated for regulated royalties auctions, if applicable; and (iii) any other volume contractually allocated to other parties before August 31, 2022. Future sales under the GSA are contingent upon the commencement of gas production.

Over the course of 2022 and 2023, together with Padana, we completed the drilling and testing of three conventional natural gas development wells (in addition to the completion of the two original Longanesi field discovery wells). Subsequently, during the first half of 2024, we and Padana completed the construction of the flow lines tying the five wells to a central processing facility, and the facility has been connected to the flow lines and to the SNAM national pipeline system. We and Padana began production of the Longanesi field in March 2025, a key milestone for our business.

From 2025 through 2027, we and Padana expect to develop a second phase of Longanesi field development aimed at bringing an additional two conventional wells online (bringing the field to seven total wells). Post 2027, we also expect to enter into a third phase of development, targeting drilling and completion of three additional wells.

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Additionally, the infrastructure installed at the Longanesi field (the flow lines and the processing unit) is expected to benefit our future development and exploration prospects in the area. Through the cash flow from Longanesi, Gradizza, and Trava once these latter two discoveries are brought on production, we plan to continue to grow both our conventional and renewable natural gas businesses. As we progress phase two and phase three of Longanesi development, we also expect to begin a new phase of exploration drilling, focused initially on our Fornace and Armonia exploration prospects.

Renewable Natural Gas Business

We expect our renewable natural gas business will methodically acquire and retrofit a significant number of existing anaerobic digester facilities in the future. We are concentrating our acquisition efforts on Brownfield Facilities in the Po Valley of northern Italy, but will seek other profitable facilities, including Greenfields, as circumstances warrant.

On March 20, 2024, we closed the acquisition of the Campagnatico Greenfield natural gas facility in Tuscany, Italy for €2,000,000, or approximately $2,150,000. The facility is fully permitted, and construction began in the fourth quarter of 2024.

In 2025 we expect to begin upgrading construction activities at two sites: Casalino (formerly known as Fattoria Delle Jersey) a Brownfield facility (a conversion of an existing AD into a biomethane facility) and Campopiano which is also a Brownfield facility. We will then sequentially stage construction at each additional facility we acquire. Both Casalino and Campopiano are currently fully permitted for production of electricity through conversion of crop and animal waste bio feedstocks. The plant assets are currently biomethane to electricity conversion assets. It is the company’s intention to begin upgrading the sites to refine biomethane into renewable natural gas through upgrading units. Following the upgrade process to transition the assets to biomethane to renewable natural gas conversion, the Company expects to sell renewable natural gas to customer(s) by trucking or piping the renewable natural gas to the interstate pipeline system (SNAM). Until the plant assets are upgraded, the Company will actively source bio feedstocks for the assets in order to produce biomethane which will be processed through reciprocating generators in order to generate electricity which is then sold onto the grid through a metered interconnection. Casalino and Campopiano derive revenues from the sale of such electricity to the local state owned electrical utility (Gestore dei Servizi Energetici SpA or “GSE”).

Led by the renewable natural gas expertise and Italian networking capabilities of Giuseppe Perrone (ex-CEO of Eni), over the past approximately 18 months, we have built a significant backlog of potential acquisition opportunities (primarily consisting of existing, operational AD’s currently producing biogas for electricity generation). These target AD’s and facilities are undergoing an extensive, and largely proprietary, due-diligence processes focused on both economic and operational feasibility. Our diligence includes, among other things, threshold financial returns, the evaluation of acquisition costs, operating costs, proximity to the existing SNAM pipeline system, feedstock availability, and optimization and expansion potential. We anticipate rapidly expanding our renewable natural gas production portfolio over the next several years.

We aim to acquire a majority working interest (80-100%) and operatorship of all renewable natural gas projects. We strive to form and enter into a joint venture with the farm (typically the seller of the existing AD infrastructure), thereby ensuring a secure supply of raw materials (biomass) and disposal of waste products (digestate). In facilities where we acquire a 100% working interest, we may enter into bespoke feedstock supply and digestate disposal contracts.

Development Plan and Permitting

Longanesi Field, Phase 1: The Production Concession has been awarded and the approved five production wells have been drilled, completed and tested. First production was achieved in March 2025.

Gradizza Field: The discovery well, which will act as the production well, has been completed and tested and all commitments under the Exploration Permit have been finished. Application for the Production Concession has been made, and the required extension of the Environmental Impact Assessment (“VIA”) has been completed and submitted for approval. Prior to first production there are two major authorizations that must be obtained: i) authorization of the Production Concession from the Emilia Romagna Region (the “Intesa”), and ii) authorization of the Production Concession from the Federal Ministry.

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Trava Field: The discovery well, which will act as the production well, has been completed and all commitments under the Exploration Permit have been finished. Application for the Production Concession has been made, and the required VIA is being finalized for submission to the Federal Ministry. Prior to first production there are three major authorizations that must be obtained: (i) approval of the VIA by the Federal Ministry, (ii) authorization of the Production Concession from the Intesa, and (iii) authorization of the Production Concession from the Federal Ministry.

Fornace Exploration Well: The required VIA has been completed and submitted to the Region and Federal Ministry for approval. The drilling application will be submitted as soon as VIA approval has been obtained from both agencies.

Gas production activities (both conventional natural gas and renewable natural gas) are subject to several environmental laws and regulations. The main reference is the Consolidated Environmental Act issued by Legislative Decree 152/2006.

The Renewable Natural Gas Development Plan (the “Development Plan”) is subject to the authorization for the construction of the biomethane facility and the production of renewable natural gas. The Development Plan is subject to environmental permitting, through Environmental Impact Assessments.

The Development of conventional natural gas is subject to and controlled by a Federal Production Concession, which is obtained after subjecting the Development Plan to technical, economic and environmental review; moreover, it is the subject of an agreement between the State and the regional government for onshore activities.

Industry

EU Demand for Secure Energy Supply and Growth in Renewable Natural Gas

We believe the EU and Italian energy markets are undergoing dramatic changes as a result of two factors: (1) Russian natural gas imports into the EU have declined approximately two-thirds (from 45% of total imports to 15% of total imports) since the outbreak of the Russia-Ukraine war due to sanctions against Russia and the cancellation of supply contracts, and (2) the shift from fossil fuels to carbon-reduced and carbon-free sources. An immediate need to replace Russian gas with a stable, secure, long-term gas supply has induced EU member nations to focus on increasing access to domestic sources of supply and new liquified natural gas (“LNG”) imports, and a series of technological, economic, regulatory, social, and investor pressures are leading the drive to decarbonize energy at a greatly accelerated pace, which is being supported by significant and long-term renewable gas incentives implemented in Italy and other EU members.

The EU finds itself in a position where reliance on conventional natural gas as a transition fuel becomes imperative for several reasons:

• Despite recent attempts in Germany, adding a significant amount of new coal-fired power in the EU is not a viable option. Domestic coal-fired electricity generation has declined to all-time lows in 2022, and much of Europe’s imported coal is from Russia. In addition, increasing coal-fired generation would require the suspension of EU carbon market regulations and the carbon emissions caps that all member nations have strongly endorsed;

• Similarly, we do not believe new nuclear power generation is a viable substitute given the lengthy permitting and construction timelines associated with such projects. Long lead times make nuclear power including attractive small nuclear reactors a multi-decade solution at best;

• Replacing Russian gas with LNG imports is very challenging, given supply constraints, limited global liquefaction capacity, and recent moves by the US to slow or stop new LNG export projects. In addition, the EU lacks sufficient LNG import terminals to increase intake significantly in a timely manner given the time and regulatory delays of constructing new LNG import facilities;

• Renewable power generation suffers from three key problems: intermittency, seasonality, and energy density. Battery technology today can only support 4-6 hours of discharge, which then requires significant and costly capital expenditures on storage to mitigate intermittency.

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• Recent advancements in Artificial Intelligence (“AI”) are leading to increased global power demand for data centers. The growth in European data center power demand may surpass the total annual power demand of some EU member states. It is anticipated that a significant portion of new data center developments will be supported by combined cycle natural gas turbine power generation. Such generation provides the steady baseload power that data centers require, and, unlike renewable power generation, does not suffer from many of the intermittency and seasonality challenges. The potential power generation and infrastructure demands that may emerge from AI technology may create natural gas demand and power price tightness that could positively impact upstream natural gas prices.

Renewable natural gas (biomethane) is compositionally identical to the biogenic natural gas in the Po Valley, can be transported on the same pipeline systems, is used by the same consumers, and offers a sustainable, low-carbon fuel that can be used to help transform the energy economy of the EU. As a result, the EU has published very aggressive targets for biomethane development (with a goal of 30% of EU natural gas by 2030), and its member states, including Italy, are supporting development with high biomethane floor prices and capital investment incentive programs to aid in financing AD conversions to upgrade biogas production to biomethane.

Social and Environmental Preferences and Investor Pressures

The effects of climate change, including extreme weather events, rising temperatures, and the increased health and socio-economic stability of at-risk populations, have emphasized the need to reduce GHGs and move toward reduced carbon energy solutions. As a result, environmentally conscious policies, initiatives, and businesses are growing in value and preference.

ESG investing has accelerated as institutional investors shift their portfolios away from carbon-intensive assets. This shift in investor sentiment has caused many large integrated energy companies to set decarbonization strategies and diversify into different forms of carbon-free and carbon-reduced energy. However, such large integrated energy companies often have expensive cost structures and cumbersome processes and generally lack the agility to pursue grass-roots smaller energy transition projects being pursued by us. We believe such factors bode well for our competitive positioning in the marketplace. We also believe sizeable integrated energy companies will look to inorganically acquire and integrate aggregated renewables businesses in the future after more nimble companies like AleAnna have built up a larger renewable portfolio of profitable biomethane facilities.

Reserve Information

Preparation of Reserve Estimates

Our reserve estimates as of December 31, 2024 and 2023 included in this prospectus are based on reports prepared by DeGolyer, our independent reserve engineer, in accordance with generally accepted petroleum engineering and evaluation principles and definitions and guidelines established by the SEC in effect at such time. Copies of the December 31, 2024 report is included as Exhibit 99.1 hereto. DeGolyer provides a variety of services to the oil and gas industry, including field studies, oil and gas reserve estimations, appraisals of oil and gas properties and exploration and development prospects and reserve reports for their clients.

Proved reserves are reserves which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward from known reservoirs under existing economic conditions, operating methods and government regulations prior to the time at which contracts providing the right to operate expires, unless evidence indicates that renewal is reasonably certain. Our proved reserves were estimated assuming a 5-year reserve life. The term “reasonable certainty” implies a high degree of confidence that the quantities of oil or natural gas actually recovered will equal or exceed the estimate. The technical and economic data used in the estimation of our proved reserves include, but are not limited to, well logs, geologic maps, well-test data, production data (including flow rates), well data (including lateral lengths), historical price and cost information, and property ownership interests. Our independent reserve engineer uses this technical data, together with standard engineering and geoscience methods, or a combination of methods, including performance analysis, volumetric analysis, and analogy. The proved developed reserves are estimated using performance analysis and volumetric analysis. The estimates of the proved developed reserves are used to estimate the proved undeveloped reserves for each proved undeveloped location (utilizing type curves, statistical analysis, and analogy). Proved undeveloped drilling locations that are more than one offset from a proved developed well utilized reliable technologies to confirm reasonable certainty. The reliable technologies that were utilized in estimating these reserves include log data, performance data, log cross sections, seismic data, core data, and statistical analysis.

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Internal Controls

Our internal staff of petroleum engineers and geoscience professionals works closely with DeGolyer to ensure the integrity, accuracy and timeliness of data furnished to DeGolyer. Periodically, our technical team meets with DeGolyer to review properties and discuss methods and assumptions used by us to prepare reserve estimates.

DeGolyer is an independent petroleum engineering and geological services firm. The independent evaluation of reserves referenced herein has been supervised by Mr. Regnald A. Boles, an Executive Vice President and Division Manager with DeGolyer, a Registered Professional Engineer in the State of Texas, and a member of the Society of Petroleum Engineers, the Society of Petroleum Evaluation Engineers, and the European Association of Geoscientists & Engineers. He has over 41 years of oil and gas industry experience. Reserve engineering is and must be recognized as a subjective process of estimating volumes of economically recoverable oil and natural gas that cannot be measured in an exact manner. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation. As a result, the estimates of different engineers often vary. In addition, the results of drilling, testing and production may justify revisions of such estimates. Accordingly, reserve estimates often differ from the quantities of oil and natural gas that are ultimately recovered. Estimates of economically recoverable oil and natural gas and of future net revenues are based on a number of variables and assumptions, all of which may vary from actual results, including geologic interpretation, prices and future production rates and costs.

For all of our properties, our internally prepared reserve estimates and the reserve reports prepared by DeGolyer, are reviewed and approved by our Executive Director, William K. Dirks, a greater than 40-year industry veteran who has successfully explored, developed, and operated reserves in multiple global jurisdictions.

The following table summarizes our proved developed and undeveloped natural gas reserves using average first-day-of-the-month closing prices for the prior 12 months and disaggregated by product.

Reserve Data

|  | December 31, 2024
|  | Natural Gas
|  | (10 6 ft 3)
Estimated proved developed reserves |  | —
Estimated proved undeveloped reserves |  | 17,621
Estimated total proved reserves |  | 17,621

The following table summarizes our proved developed and undeveloped reserves using average first-day-of-the-month closing prices for the prior twelve months and disaggregated by discovery.

|  | December 31, 2024
|  | Longanesi |  | Gradizza |  | Trava |  | Total
|  | (10 3 ft 3)
Proved undeveloped reserves |  | 17,241 |  | 380 |  | — |  | 17,621
Total proved reserves |  | 17,241 |  | 380 |  | — |  | 17,621

Proved Undeveloped Reserves

Our 2024 proved undeveloped reserves decreased slightly compared to 2023 primarily due to slight changes in the forecasted startup dates for Longanesi and Gradizza. The following table provides a roll-forward of our proved undeveloped reserves.

|  | Proved Undeveloped Reserves
|  | (10 6 ft 3)
Balance at January 1, 2024 |  | 17,689 |
Revision of previous estimates |  | — |
Extensions, discoveries and other revisions |  | (68 | )
Balance at December 31, 2024 |  | 17,621 |

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As of December 31, 2024, we had no wells with proved undeveloped reserves that had remained undeveloped for more than five years from their time of booking. Our Longanesi, Trava and Gradizza wells are classified by DeGolyer as proved undeveloped reserves as such wells have not yet started production and require future investments to install production pipelines and production facilities prior to being fully completed and producible.

On May 28, 2024, we reached a settlement agreement (the “Blugas Settlement Agreement”) with Blugas Infrastructure S.r.l. (“Blugas”) regarding the Blugas overriding royalty interest (“ORRI”) whereby Blugas was entitled to physical delivery of 20% of the first 350 million standard cubic meters (approximately 2,472 106ft3) produced from the Longanesi field. Under the terms of the Blugas Settlement Agreement, we paid Blugas approximately €5 million, plus an additional €1.1 million in applicable VAT. In exchange, we were released from any future liability related to the Blugas ORRI. As a result of the transactions contemplated by the Blugas Settlement Agreement, our 33.5% working interest (net revenue interest) in the Longanesi field, as established under the terms of the Unified Operating Agreement arrangement originally signed between ENI and Grove and dated September 26, 2009, is now unencumbered except for normal government royalties (10%). The Blugas Settlement was accounted for as an acquisition of the Blugas ORRI claim with a corresponding increase to the expected future cash flows from our reserves. Our year-end December 31, 2023 reserve quantities included the 20% of 350 million standard cubic meters (approximately 2,472 106ft3) allocable to the Blugas ORRI in our proved gas reserves. However, the required payments to Blugas associated with the sale of such quantities were reflected as cash outflows (costs) in our year-end December 31, 2023 reserve report as if such amounts were paid to Blugas. Following settlement, our year-end December 31, 2024 reserve quantities continue to include the 20% of 350 million standard cubic meters (approximately 2,472 106ft3), however, the previously required payments to Blugas associated with the sale of such quantities are no longer reflected as cash outflows (costs) as if such amounts were paid to Blugas. As the cash outflows (costs) are no longer reflected as if paid to Blugas, such amounts are reflected in our December 31, 2024 reserve report as allocable to our unencumbered 33.5% working interest.

Present Value of Future Net Cash Flows Discounted at 10%

The following table provides the estimated future net cash flows from proved reserves, the present value of those net cash flows discounted at a rate of 10% (PV-10) and the prices used in projecting net cash flows over the past two years. Our reserve estimates and related cash flows do not include any probable or possible reserves.

|  | Years Ended December 31,
|  | 2024 |  | 2023
|  | (Thousands, unless otherwise noted)
Future net cash flows(a) |  | $ | 130,333 |  | $ | 132,492
Present value of net cash flows discounted at a rate of 10%(b) |  |  | 107,202 |  |  | 102,672
Prices |  |  |  |  |  |
Natural gas price ($/103ft3)(c) |  | $ | 11.73 |  | $ | 14.13

____________

(a) Future net cash flows represent future cash flows which are reduced by estimated production costs, administrative costs, costs to develop and produce the proved reserves and abandonment costs, all based on current economic conditions at each year-end. This amount excludes future income taxes and is prior to any discounting.

(b) Present value of net cash flows represents future net cash flows discounted to present value using a discount rate of 10%. Such amount also excludes future income taxes. See “Reconciliation of Standardized Measure to PV-10” for a calculation of the standardized measure of estimated future net cash flows from natural gas and oil reserves.

(c) Gas prices are based on a reference price. Gross gas price is calculated as the unweighted arithmetic average of the first day-of-the-month price prevailing in Italy for each month within a 12-month period prior to the end of the reporting period. The volume-weighted average price attributable to the estimated proved reserves was $11.73 and $14.13 per thousand cubic feet of gas for the year ended December 31, 2024, and 2023, respectively.

Future net cash flows represent projected revenues from the sale of proved reserves net of production and development costs (including transportation and gathering expenses, operating expenses and production taxes). Revenues are based on a twelve-month unweighted average of the first-day-of-the-month pricing, without escalation. Future cash flows are reduced by estimated production costs, administrative costs, costs to develop and produce the proved reserves and abandonment costs, all based on current economic conditions at each year-end. There can be no assurance that the proved reserves will be produced in the future or that prices, production or development costs will remain constant. There are numerous uncertainties inherent in estimating reserves and related information.

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See Note 17 to the financial statements included in this prospectus for further discussion of the preparation of, and year-over-year changes in, our reserves estimate and calculation of the standardized measure of estimated future net cash flows from natural gas and oil reserves.

As previously noted, the Blugas settlement was accounted for as an acquisition of the Blugas ORRI claim with a corresponding increase to the expected future cash flows from our reserves. Our year-end December 31, 2023 reserve quantities included the 20% of 350 million standard cubic meters (approximately 2,472 106ft3) allocable to the Blugas ORRI in our proved gas reserves. However, the required payments to Blugas associated with the sale of such quantities were reflected as cash outflows (costs) in our year-end December 31, 2023 reserve report as if such amounts were paid to Blugas. Following settlement, our year-end December 31, 2024 reserve quantities continue to include the 20% of 350 million standard cubic meters (approximately 2,472 106ft3), however, the previously required payments to Blugas associated with the sale of such quantities are no longer reflected as cash outflows (costs) as if such amounts were paid to Blugas. As the cash outflows (costs) are no longer reflected as if paid to Blugas, such amounts are reflected in our December 31, 2024 reserve report as allocable to our unencumbered 33.5% working interest.

Reconciliation of Standardized Measure to PV-10

The present value of net cash flows discounted at a rate of 10%, or, “PV-10,” is derived from the standardized measure of discounted future net cash flows, which is the most directly comparable GAAP financial measure. PV-10 is a computation of the standardized measure of discounted future net cash flows on a pre-tax basis. PV-10 is equal to the standardized measure of discounted future net cash flows at the applicable date, before deducting future income taxes, discounted at 10 percent. We believe that the presentation of PV-10 is relevant and useful to investors because it presents the discounted future net cash flows attributable to our estimated proved reserves prior to taking into account future corporate income taxes, and it is a useful measure for evaluating the relative monetary significance of our oil and natural gas assets. Further, investors may utilize the measure as a basis for comparison of the relative size and value of our reserves to other companies. We use this measure when assessing the potential return on investment related to our oil and natural gas assets. PV-10, however, is not a substitute for the standardized measure of discounted future net cash flows. Our PV-10 measure and the standardized measure of discounted future net cash flows do not purport to present the fair value of our oil and natural gas reserves.

The following table provides a reconciliation of the GAAP standardized measure of discounted future net cash flows to PV-10 (non-GAAP) at December 31, 2024 and 2023:

|  | Years Ended December 31,
|  | 2024 |  | 2023
|  | (Thousands, unless otherwise noted)
Standardized measure of discounted future net cash flows |  | $ | 89,033 |  | $ | 69,924
Present value of future income taxes discounted at a rate of 10% |  |  | 18,169 |  |  | 32,748
Present value of net cash flows discounted at a rate of 10% (PV-10) |  | $ | 107,202 |  | $ | 102,672

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Acreage

The following table summarizes our acreage as of December 31, 2024 and 2023. As AleAnna has not commenced production, the Company has not yet classified any acreage as developed (productive) acreage.

|  | December 31, 2024 |  | December 31, 2023
Production Concessions(1) |  |  |  |
Total gross productive acreage |  | — |  | —
Total net productive acreage |  | — |  | —
Exploration Permits(2) |  |  |  |
Total gross productive acreage |  | — |  | —
Total net productive acreage |  | — |  | —
Applications(3) |  |  |  |
Total gross productive acreage |  | — |  | —
Total net productive acreage |  | — |  | —
Total gross productive acreage |  | — |  | —
Total net productive acreage |  | — |  | —
Production Concessions(1) |  |  |  |
Total gross undeveloped acreage |  | 24,142 |  | 24,142
Total net undeveloped acreage |  | 19,710 |  | 19,710
Exploration Permits(2) |  |  |  |
Total gross undeveloped acreage |  | 682,802 |  | 682,802
Total net undeveloped acreage |  | 682,802 |  | 682,802
Applications(3) |  |  |  |
Total gross undeveloped acreage |  | 1,623,209 |  | 1,623,209
Total net undeveloped acreage |  | 1,623,209 |  | 1,623,209
Total gross undeveloped acreage |  | 2,330,153 |  | 2,330,153
Total net undeveloped acreage |  | 2,325,721 |  | 2,325,721

____________

(1) Encompasses three distinct production concession areas including Longanesi, Valle del Mezzano (Trava), and Gradizza. No expiries prior to 2032.

(2) Encompasses 10 distinct permits. AleAnna has an active permit extension program in place. In the event that production is not established or if extensions are not granted by the Italian government, 130,558 net acres will expire by December 31, 2026 and an additional 331,845 acres will expire by December 31, 2027. Included in the 682,802 are three permits totaling 104,815 net acres originally held in suspense pending review and revision of the PiTESAI as further described in the “Governmental Regulations” section below. The Italian Government has initiated a procedure to return to Aleanna all of the acres affected by the PiTESAI.

(3) Encompasses 14 distinct areas and applications. Applications are rights of mineral development controlled by AleAnna whose activation may be deferred. AleAnna has not yet initiated activation, but has the right to do so in the future. Once AleAnna initiates activation the 1,623,209 net acres will have initial permit periods of six years.

Productive Wells

We did not have any productive wells as of December 31, 2024, 2023, or 2022. As of December 31, 2024, our Longanesi, Trava and Gradizza wells all required future investments to install production pipelines and production facilities prior to being fully completed and producible. As a result, as of December 31, 2024, our wells were classified by DeGolyer as proved undeveloped reserves as such wells had not yet started production.

Drilling Activities

Our primary activities currently involve the tie-in of three Longanesi development wells together with our working interest partner, Padana. Our recent drilling activity consisted of the following: no activity during year-to-date December 31, 2024, drilling and completion of two gross Longanesi development wells (0.67 net wells to our interest) during the year ended December 31, 2022, and drilling and completion of one gross Longanesi development well and workover and completion of one additional Longanesi development well (0.335 net to our interest) during the year ended December 31, 2023. We had no other exploratory or development drilling during the year-to-date December 31,

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2024 or the years ended December 31, 2023 or 2022. Our Longanesi, Trava and Gradizza wells were classified by DeGolyer as proved undeveloped reserves as such wells had not yet started production and required future investments to install production pipelines and production facilities prior to being fully completed and producible. Following tie-in of the Longanesi wells and the installation of a temporary processing facility, we and Padana achieved first production of the five wells in the Longanesi field in March 2025. The permanent processing facility is expected to be constructed over the course of 2025 and early 2026 and commissioned in mid-2026.

Net Volumes Sold, Prices and Production Costs

As of December 31, 2024 and December 31, 2023, we have not generated any revenue from our operations other than from sales of electricity from two renewable gas assets that were purchased in July 2024. As of December 31, 2023 and 2022, we had not derived revenue from our principal business activities.

Delivery Commitments

We are not currently party to any long-term delivery commitments as of December 31, 2024, 2023, or 2022.

Governmental Regulations

With regard to environmental laws and compliance, the activities are subject to Environmental Impact Assessment, whose main rules are provided by the Consolidated Environmental Act issued by Legislative Decree 152/2006.

Environmental laws and regulations and environmental permitting require significant investments from the company to ensure compliance with laws and regulations. This entails the need for a structure that constantly monitors compliance activities.

Conventional Natural Gas

Our operations are subject to stringent and complex laws and regulations governing environmental protection, human health and safety, and long-term “sustainability”. We are required to obtain certain permits, requiring approval at both the Italian national and regional government levels, to construct and operate our conventional facilities, which will contain constraints including those related to air emissions, solid and hazardous waste management, water quality, and control of construction/industrial traffic. These permits can be difficult and time-consuming to obtain and maintain. We have spent over a decade acquiring necessary permits required for the development of our Conventional business, and while we view this as a competitive advantage, our ability to obtain these permits in the future may be impacted by opposition from citizens or other groups or other political pressures. Compliance with such laws and regulations can be costly, and noncompliance can result in substantial penalties.

The Italian hydrocarbons industry is regulated by a combination of constitutional provisions, statutes, governmental decrees and other regulations that have been enacted and modified from time to time, including legislation enacted to implement EU requirements (collectively, the “Hydrocarbons Laws”).

Pursuant to the Hydrocarbons Laws, all hydrocarbons existing in their natural condition in strata in Italy or beneath its territorial waters (including its continental shelf) are property of the State. Exploration activities require an exploration permit, while production activities require an exploiting concession granted by the Ministero dell’Ambiente e della Sicurezza Energetica — MASE or, in some specific cases (e.g. special-status region) by the Region.

In particular oil and gas exploration can be undertaken after the award of an exploration license that can last up to twelve years, provided that the permit holder complies with the approved exploration program. If the permit holder drills and discovers an exploitable hydrocarbon field, it has a right to obtain a production concession. All exploration and production activities are subject to environment assessment procedures.

Hydrocarbon exploration and production activities in Italy are governed by Law no. 6/1957, “Exploration and production of liquid and gaseous hydrocarbons”. Mining titles are granted by a Decree of MASE. The two main types of mining titles are:

(a) Exploration permits — exclusive mining titles that can be requested on areas with a maximum footprint of 750 km2. If multiple operators request the same area, MASE manages a competitive process to select the permit holder. In addition to an initial three-year validation period, there are two possible extension periods of three years

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each. However, such periods may be subject to suspension for justified reasons. The exploration permit allows the acquisition of geophysical data as well as the permission to drill one or more exploratory wells. If the exploratory well yields a positive result and a new hydrocarbon field is identified, the operator may apply for a production concession, which, once granted, allows the deposit itself to be brought into production.

The reference legislation for issuing the exploration permit is the following:

• art. 8 “Granting of permits”, paragraph 1, of the Presidential Decree. 18 April 1994, n. 484 “Regulation governing the procedures for awarding prospecting or exploration and granting concessions for the production of hydrocarbons on land and at sea”;

• art. 6 “Awarding of the exploration permit, its dimensions and duration”, paragraph 4, of law 9 January 1991, n. 9 “Regulations for the implementation of the new national energy plan: institutional aspects, hydroelectric plants and power lines, hydrocarbons and geothermal energy, self-production and tax provisions”;

• for onshore, art. 1, paragraph 7, letter n) of law 239/2004 “Reorganization of the energy sector, as well as delegation to the Government for the reorganization of the provisions in force on energy”.

• The exploration permit is issued following a single procedure, governed by article 1 paragraphs 77 and 79 of law 23 August 2004, n. 239 and subsequent amendments. MASE reviews the project after hearing the opinion of a consultative body, the Ministerial commission on hydrocarbons (CIRM), within which the competent state and regional administrations are represented. The projects are subjected to the environmental eligibility procedure and/or the expression of an environmental compatibility judgment by the MASE or the Region concerned. MASE then issues onshore permits in agreement with the regions involved.

(b) Production Concessions are exclusive mineral titles requested on a portion of the exploration permit area where a new hydrocarbon field was discovered (with a maximum area of 300 km2). In addition to an initial validation period of 20 or 30 years, an operator may apply for further extension periods of five or 10 years. All activities relating to the production of hydrocarbons can be carried out within the scope of a production concession, including the drilling of development wells and construction of facilities. Production concessions are awarded to the holders of exploration permits so long as liquid and/or gaseous hydrocarbons are found and so long as the operator demonstrates adequate economic and technical capacities.

The production concession decree is granted and issued by MASE and contains all the requirements and constraints established by the various bodies that examined the project during the administrative procedure. The concession holder may freely sell the products extracted from the hydrocarbon field and must pay a royalty to the national and local governments. Yearly rentals are due based on the areas under the permits and are due to the national government.

The concession holder has an exclusive right on exploration, development and production activities, sustaining all the operational risks and costs related to the exploration and development activities, and it is entitled to the productions realized. As a compensation for mineral concessions, pays royalties on production and taxes on oil revenues to the state in accordance with local tax legislation.

Proved reserves to which we are entitled are determined by applying our share of production to total proved reserves of the contractual area, in respect of the duration of the relevant mineral right.

In general, we are required to pay income tax on income generated from production activities. The taxes imposed upon gas production profits and activities may be substantially higher than those imposed on other businesses.

The initial duration of an exploration permit is six years, with the possibility of obtaining two three-year extensions and an additional one-year extension to complete activities underway. AleAnna has an active permit extension program in place. In the event that production is not established or if extensions are not granted by the Italian government, AleAnna’s permits will expire in December 31, 2026 and December 31, 2027. Applications are rights of mineral development controlled by AleAnna whose activation may be deferred. AleAnna has not yet initiated activation, but has the right to do so in the future. Once AleAnna initiates activation the respective net acres will have initial permit periods of six years. Upon each of the three-year extensions, 25% of the area under exploration must be relinquished

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to the State (only for initial acreage larger than 300 square kilometers). The initial duration of a production concession is 20 years, with the possibility of obtaining a ten-year extension and additional five-year extensions until the end of the field economic life.

These provisions had to be coordinated with a new law effective as of February 12, 2019 (Law 12/2019, conversion of Decree-Law 135/2008 — “D.L. Semplificazioni”) and further amendments, which requires certain Italian administrative bodies to define and adopt a plan (PiTESAI) aiming to identify areas suitable for exploration, development, and production of hydrocarbons in the national territory, including the territorial seawaters. Such plan was adopted on December 28, 2021 with Ministerial Decree, in accordance with the article 11-ter of Decree-Law 135/2018.

However, PiTESAI has been considered too restrictive by industry operators (including AleAnna) which lodged several appeals against the PiTESAI before the Lazio Regional Administrative Court — Rome (TAR Lazio). On February 12, 2024, TAR Lazio with rulings no. 2858 and no. 2872 declared void the PiTESAI. MASE did not file an appeal before the Council of State within the appeal period in order to restore the validity of the PiTESAI and began a procedure to return all of the acres affected by the PiTESAI, once acquired for those operators who want to reacquire their mining titles and permit applications with the original extension. This procedure aims to restore the integrity of all the titles affected by the PiTESAI and returns to the operators of all of the suitable areas for hydrocarbon exploration, development and production activities.

Therefore, exploration permits maintain their efficacy in areas identified as suitable and limited to gas exploration target.

Starting from June 1, 2019, the annual fee for all licensees (exploration permits and production concessions) have been increased 25 times.

In 2019 the Decree-Law 124/2019, converted into Law 157/2019, established at article 38 the property tax on marine structures (IMPI) starting from year 2020.

On March 1, 2022, the Italian government issued a first Decree-Law (Decree-Law 17/2022 — “ D.L. Energia”) aimed at boosting the national production by mitigating the effects of PiTESAI. This was converted into law on April 27, 2022 (Law 34/2022).

A second Decree-Law, with the same objectives, was issued on December 9, 2023 (Decree-Law 181/2023), promoting new upstream development opportunities converted into law on February 2, 2024 (Law 11/2024).

On October 11, 2024, the Council of Ministers approved the Decree-Law 153/2024 converted into Law 191/2024 (D.L. Ambiente), which amended several articles of the Decree-Law 135/2018. Paragraph 1 of article 2 of the 153/2024 repealed paragraphs 1, 2, 3, 4, 5, 6, 7, 8 and 13 of Article 11-ter of Decree-Law 135/2018, and the PiTESAI was therefore annulled. The measures adopted by the MASE following the adoption of the PiTESAI such as revocation and re-implementation measures were also annulled. Following the repealing of paragraph 13 of article 2 of the Decree-Law 135/2018, the public utility character of hydrocarbon prospecting, exploration and production activities has been recognized.

Furthermore, paragraph 2 of article 2 of the Decree-Law 153/2024 confirmed the prohibition established by PiTESAI on the granting of new oil production licenses on the national territory and at sea, however, operators who have already been granted oil or oil and gas licenses may continue their activities, even for the purpose of granting concessions; even concessions for the production of liquid hydrocarbons that have already been granted may continue their production activities until the deposit found is fully developed.

Article 2, paragraph 3, of the Decree-Law 153/2024 stated that the granting of extensions of hydrocarbon production concessions must also take into account the reserves and extraction potential still to be produced and the time required to complete their rational production up to the useful life of the deposit. The concession area that is functional for production and the research and development activities still to be carried out must also be duly taken into account, with the areas no longer functional being re-zoned.

Article 2, paragraph 4 of the Decree-Law 153/2024 reduced the limit of 12 nautical miles for upstream activities to nine nautical miles, amending the article 6, paragraph 17 of the Environmental Code (Legislative Decree 152/2006).

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Article 2, paragraph 5 of the Decree-Law 153/2024 allowed for the release of concessions in the Adriatic Sea for which applications had already been submitted at the time the Decree-Law 153/2024 went into force, provided that the party concerned complies with the long-term supply procedures. In addition, the fields in question must have the potential to produce a certain amount of gas reserves above a threshold of 500 mmscfd.

Regardless of the validity and the effects of PiTESAI, such plan did not entail any significant and adverse consequence on AleAnna’s development and producing activities in relation to its Italian concessions and concession applications. Some permits where investments on exploration had been made were affected by the plan and part or all of their areas was declared incompatible. Since the PiTESAI was voided, AleAnna now hopes to be able to start again exploration activity on part of the areas declared incompatible by the PiTESAI. On December 13, 2024, AleAnna, as requested by MASE, notified MASE of its willingness to reacquire the mining titles and permit applications with the original extension. AleAnna has filed appeals that are still pending with the administrative Courts to request payments of indemnity for loss of such areas.

Royalties

The Hydrocarbons’ Laws require the payment of royalties for hydrocarbon production. As per Legislative Decree No. 625 of November 25, 1996, subsequent modifications and integrations (the last modification was introduced by Law 160/2019 — Budget Law 2020, art. 1 par. 736 & 737) and Law Decree No. 83 of June 22, 2012, royalties are equal to 10% for gas and oil productions onshore, to 10% for gas and 7% for oil offshore, with exemptions only for on shore gas concessions with production lower than 10 Msmc/year and off shore gas concessions with production lower than 30 Msmc. (Only in the Autonomous Region of Sicily, following the Regional Law No. 9 of May 15, 2013, royalties onshore for oil and gas are equal to 20.06%, with no exemptions).

Environmental Regulation

Exploration and production of conventional natural gas is highly regulated and is subject to environmental laws and compliance, whose main rules are provided by the Consolidated Environmental Act issued by Legislative Decree 152/2006. Our activities are subject to Environmental Impact Assessments. Environmental laws and regulations and environmental permitting require significant investments to ensure compliance. For this reason, a structure that constantly monitors compliance activities is needed.

Our operations are subject to stringent and complex laws and regulations governing environmental protection, human health and safety, and long-term “sustainability”. Oil and gas companies are required to obtain certain permits, requiring approval at both the Italian national and regional government levels, to construct and operate conventional facilities, which will contain constraints including those related to air emissions, solid and hazardous waste management, water quality, and control of construction/industrial traffic. These permits can be difficult and time-consuming to obtain and maintain. We are acquiring necessary permits required for the development of its conventional business, and while we view this as a competitive advantage, our ability to obtain these permits in the future may be impacted by opposition from citizens or other groups or other political pressures. Compliance with such laws and regulations can be costly, and noncompliance can result in substantial penalties.

Italian Gas Market Regulations

In the last decade a number of new rules have been introduced in order to improve liquidity and efficient functioning of the Italian wholesale gas market, fostering competition and at the same time improving the system security of supply. Among such new rules, it is worth mentioning the market-based mechanisms for the allocation of storage capacities and of regasification capacities. The past allocation criteria based on tariffs has been replaced with new auction mechanisms that enabled market players to express the market-value of storage and of regasification capacities, while at the same time ensuring the allowed revenues of storage operators and LNG terminal operators by means of specific parallel measures.

An organized market platform (MGAS) for gas trading and gas balancing market, managed by the independent operator Gestore dei Mercati Energetici (GME) also acts as a central counterparty, where different market participants (including the Transmission System Operator — TSO) can carry out spot and forward transactions at the “Punto di Scambio Virtuale” (PSV — Virtual Trading Point). In addition, since February 2018 voluntary market making activity has been introduced in the spot section of the gas exchange MGAS: such activity is based on the service

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provided by some liquidity providers, in order to boost liquidity and trading activity on the same exchange, initially for the day-ahead market but with possible future extension to the within-day section and to the forward section of the MGAS.

In addition, a gas balancing regime has entered into force since October 2016 as an evolution of the one already in place and in compliance with the EU regulatory framework. This system is based on the principle that network users have to balance their daily position, also in accordance with the timely information provided by the TSO about the daily gas consumption. The new gas balancing regime provides the incentive for shippers to balance their position via penalizing imbalance prices and at the same time provides the possibility for shippers to modify intra-day their gas flow nominations and to trade on the market with other shippers and/or with the TSO itself (that can access the market under some constraints, in order to address overall system balancing needs that may arise on top of shippers’ activities).

Following the liberalization of the natural gas sector introduced in the year 2000 by Decree No. 164, prices of natural gas in the wholesale market which includes industrial and power generation customers are freely negotiated. However, the ARERA retains a power of surveillance on this matter as per Law No. 481/1995 (establishing the ARERA) and Legislative Decree No. 164/2000. Furthermore, the ARERA is still entrusted (as per the Presidential Decree dated October 31, 2002) with the power of regulating natural gas prices to residential customers, also with a view of containing inflationary pressure deriving from increasing energy costs. Consistently with those provisions, companies which sell natural gas to residential customers are currently required to offer to those customers the regulated tariffs set by ARERA beside their own price proposals.

In 2013, a new tariff regime was fully enacted by ARERA targeting Italian residential clients who are entitled to be safeguarded in accordance with current regulations. Clients who are eligible for the tariff mechanism set by the ARERA are residential clients. With Resolution No. 196 effective from October 1, 2013, the ARERA reformulated the pricing mechanism of gas supplies to those customers by providing a full indexation of the raw material cost component of the tariff to spot prices at the TTF (Title Transfer Facility) hub in Northern Europe, replacing the then current regime that provided a mix between an oil-based indexation and spot prices.

This tariff regime also reduced the tariff components intended to cover storage and transportation costs. Finally, it also increased the specific pricing component intended to remunerate certain marketing costs incurred by retail operators, including administrative and retention costs, losses incurred due to customer default and a return on capital employed.

This new gas tariff indexation aiming at safeguarding the households was initially intended to remain effective till July 1, 2019 (as provided by Law 124/17). However, this deadline had been already prorogated by one year (as per Law Decree 91/2018), and finally has been prorogated to January 2024. From that point onwards, in Italy households other than vulnerable customers will no longer have access to regulated tariffs for gas supplies. Consumers will have to choose among the different pricing proposals made by gas selling companies, while only vulnerable customers will be entitled to the regulated tariff after January 2024. The ARERA has established that gas selling companies comply with certain requirements about the offerings to customers which include at least two pricing indexations (fixed and variable), both complemented with contractual conditions regulated by the ARERA. This regulatory development might increase competition in the Italian retail market for selling gas.

Given the context of rising prices that occurred between 2021 and 2022 in gas market, ARERA carried out a series of investigations to evaluate interventions on commodity prices and then decided to switch the gas raw material reference from TTF to PSV, with monthly update of the component covering wholesale natural gas supply costs for regulated customers.

Other Key Regulatory Developments

Within the scope of the costs and criteria for accessing the main logistic infrastructures of the gas system, the main risk factors for the business are linked to the periodic processes for defining the economic conditions and the current rules for the services. The regulation criteria for gas transportation tariffs in Italy have recently been redefined for the four-year period 2024-2027, but the re-definition of transportation tariffs criteria at pre-established deadlines, as well as the timely definition on an annual basis of the specific applicable tariff values, is an element that all European countries have in common and which in the future could determine impacts on logistic costs.

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Moreover, the energy crisis scenario that materialized in 2022 has directed legislators, at European and individual country level, towards evolutions of the legislation and the consequent regulations that can impact the market dynamics, with the aim of containing prices for end customers and improve the security of supplies (e.g. possible obligations to reduce final consumption, caps on prices of derivatives on wholesale gas products traded on regulated markets, possible storage obligations, obligations of ex-ante notification to the European Commission concerning new supply contracts).

The Italian Government adopted a number of various measures to contain retail prices such as:

• cancellation of general system charges;

• strengthening of social bonuses; and

• decrease of VAT in the gas sector (until December 31, 2023).

In the medium term, it is likely that gas demand at European level will be supported by the need of accelerating the phase-out of coal-based power generation in view of the decarbonization targets. On the other side, with the implementation of the EU Green Deal and of the subsequent and more ambitious decarbonization interventions, in the coming years the regulation of the gas sector will presumably be affected by potentially significant changes, as a consequence of adjustments in the market design and/or new obligations or constraints on operators in the sector which will accompany the evolution of European regulations, in the context of energy transition and consistently with the decarbonization objectives of the energy sector (including the related objectives for the development of renewable or decarbonized gases, for the promotion of technologies enabling greater integration between the electricity and gas sectors, for the reduction of methane emissions). These changes might cause pressure on the natural gas business, but on the other side they will likely open and support new business opportunities in the renewable and decarbonized gases business that we are ready to pursue.

Renewable Natural Gas

The permitting framework provided by the Legislative Decree No. 28/2011 requires for the construction and operation of biomethane production facilities and related modification projects:

• the “notification” to the competent authority for the modifications are non-substantial;

• the “Simplified Authorization Procedure” (“S.A.P.”):

a) “for new facilities with a production capacity, as defined in accordance with Article 21, paragraph 2, not exceeding 500 standard cubic meters/hour;

a-bis) for partial or complete reconversion to biomethane production of power generation facilities fueled by biogas, landfill gas or residual gas from purification processes;

a-ter) for developments on operating biomethane production facilities that do not result in an increase in the area already subject to authorization, regardless of the resulting amount of biomethane fed into the grid as a result of such developments, subject to the following conditions:

1. in the case of grid-connected facilities, there is the willingness of the grid operator to inject the additional volumes resulting from the implementation of the developments;

2. the operations do not involve any changes in the types of matrices already authorized;

3. the nameplate of the upgrading system indicates the production capacity value resulting from the implementation of the developments;

4. any increase in areas dedicated to anaerobic digestion is no more than 50 percent of those already authorized.”

• the “Sole Authorization” (“S.A.”) in other cases.

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The application for the S.A. procedure, defined by Legislative Decree No. 387/2003, is submitted by the proponent to the competent region, along with the final project and the plan for decommissioning and restoration works in the area (Ministerial Decree 10.09.2010). Once the documents have been verified, within 30 days the Region shall proceed to convene the “service conference” which is the meeting attended by all public bodies interested in the project to give opinions of competence or request clarifications from the proponent. The proceedings for the S.A. are ordinarily closed within 90 days of the services conference, except in cases where the “environmental impact assessment” proceedings are started or in case of suspension of deadlines for documentary additions. The procedure ends with the adoption of the managerial determination of the competent region.

The application for the S.A.P. procedure, defined by Legislative Decree No. 28/2011, is submitted by the proponent to the municipality at least 30 days before the start of work on the plant. The application must be supported by the technical drawings of the project. Within 30 days of the application, the municipality must verify the conditions of the S.A.P.; alternatively, after the 30-day period has elapsed, the application is considered granted.

During 2023 and 2024, through several decrees, the procedures for obtaining authorization for the conversion of existing AD’s (or the construction of new biomethane facilities) were simplified, with key regulatory protocols as follows:

• Law No. 95 of July 26, 2023, introduced urgent measures to simplify the procedures for authorization and connection to the national grid. In particular, the new measures indicate how to obtain authorization for the conversion or construction of biomethane facilities, which also included a simplified municipal authorization procedure for facilities up to 500 smc/h.

Renewables Regulation in the Biomethane Production Sector

In order to support the achievement of the renewables target in the transport sector established by the EU and national laws, the Ministerial Decree of March 2, 2018 and of September 15, 2022, provide the legislative framework to incentivize the production of both biomethane and other advanced biofuels to be used in the transport sector. The Decrees provide incentives for biogas facilities that are converted to biomethane production.

The incentive consists in an allocation of a Certificate (CIC) for every 10 Gcal of biomethane produced and partial subsidies on investments on biomethane facilities. The certificate has a market value since fossil fuel marketers have to sell a minimum percentage of biofuels annually, for which they receive the same Certificates.

In order to access to incentives, producers must comply with legal and technical regulations governing the quality and certification of the produced biomethane, verified by the competent Authority (Gestore dei Servizi Energetici, GSE).

These measures aim to favor advanced biofuels production through the valorization of waste, notably of agricultural and farm/zootechnical waste.

Regarding biomethane, the incentive scheme has been replaced, following approval by the European Commission, by the Ministerial Decree of September 15, 2022. The mechanism consists of an operating aid — in the form of a CfD linked to the market value of natural gas and of the biomethane Guarantee of Origin, auctioned through a competitive procedure — and an investment aid — covering up to 40% of the eligible investment costs and funded by the NRRP. The mechanism differentiates between new facilities and refurbishments and between agro or waste-based facilities. Law 136/2023 introduced an inflation-linked indexation for the base tariffs set by MD September 15, 2022. In every auction, tariffs will be updated following the total inflation accrued between November 2021 and the auction’s opening month.

At the end of 2020, the Ministerial Decree of October 2014 on conditions, criteria and implementation of biofuels (conventional and advanced) obligations for suppliers was modified. Among the novelties, were introduced the increase of the overall 2021 target from 9% to 10% and a new additional target of 0,5% of advanced liquid biofuels to be mandatory blended by each supplier (outside the incentive scheme provided by DM 2018).

Law 238/2021 (European Law 2019-2020) confirmed the GHG saving requirement (6%) previously set for the year 2020 only and revised the calculation methodology for the current 7% maximum threshold for food-and-crop derived biofuels. The law excludes from the calculation fuels based on double counting feedstock.

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The Directive (EU) 2018/2001 on the promotion of the use of energy from renewable sources has been transposed with the Legislative Decree No 199/2021. The Decree set new targets for RES penetration in the transport sector (16%) and introduced some innovations in the transport sector’s regulatory framework: i) palm-oil, PFAD and EFB based fuels cannot contribute to RES targets in the transport sector. However, they can be taken into account if certified as low-ILUC risk ii) biomethane support schemes — as defined by the Ministerial Decree of March 2, 2018 — have been updated iii) Recycled Carbon Fuels count as renewable towards the general target, on the basis of the upcoming EU delegated acts and iv) confirms the use of some wastes as feedstock for the production of biofuels.

Occupational Health, Safety and Environment Legislation

Our activity is subject to Italian and European legislation on environmental protection and safety in the workplace. Although we carry out our activities in compliance with these laws and regulations, the risk of incurring unforeseen charges, including claims for compensation for damage to property and persons, as well as reputation risk, are inherent in the nature of the activities carried out by us.

In particular, our industrial activities in the hydrocarbon exploration, development, and production sectors and biomethane production are exposed to operational risks related to the chemical and physical characteristics of raw materials and products (e.g., flammability, toxicity, instability) and to technical failures, equipment malfunctions, containment leaks, well accidents, and incidents that can result in events such as explosions, fires, and spills of oil, gas, and other harmful substances. These risks are influenced by the specifics of the territorial areas in which operations are conducted, the complexity of industrial activities, and the objective technical difficulties in carrying out recovery and containment of hydrocarbons or other liquid chemicals spilled into the environment or harmful emissions into the atmosphere, closure and safety operations of damaged wells or production facilities, or in case of uncontrolled release of oil or natural gas from a well or from a biomethane production plant. Severe soil, groundwater, or air pollution caused by operational activity could result in modest oil or other contaminant spills or small gas spills due to lack of maintenance, corroded or obsolete piping or infrastructure, lack of controls, or other factors, which if protracted over time could cause significant damage. For these reasons, activities in the hydrocarbon and biomethane sectors are subject to strict regulations to protect the environment and the health and safety of people, both at the national/local level and through international protocols and conventions.

We may in the future be required to meet compensation obligations arising from the violation of environmental regulations, as well as to incur significant investments to comply with obligations from applicable environmental regulations.

Occupational safety, health and hygiene are kept under control by continuously updating and carrying out legally required inspections.

We are aware that our activities could produce effects that interfere with the protection of occupational health, safety, and the environment and that the same activities could have an impact on the fulfillment of the requirements of workers and other stakeholders.

The working relationship for employees in Italy is regulated by the pertaining collective work agreement, which provides for the basic standard conditions applicable depending on the employee’s level of seniority. Levels of welfare and social security are guaranteed by Italian working regulation. In order to maintain a workplace free of any discrimination and to establishing appropriate measures for health and safety at work, as well as for professional development, equal opportunities and work-life balance, we regularly review the working place conditions and assesses related regulations.

We therefore recognize the proper management of these aspects as a strategic objective. The importance of respecting health, occupational safety and the environment are not considered as mere regulatory compliance, but as dutiful behaviors directed toward respecting the natural and fundamental rights of the individual. In this regard, we are committed to:

• carrying out our activities in compliance with current laws on occupational health and safety prevention, environment and current regulations with impact on quality aspects and voluntarily subscribed standards;

• promote activities that can directly or indirectly ensure: the protection and preservation of occupational health and safety, the environment, biodiversity and ecosystems, including in the interest of future generations;

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• consider prevention in occupational health and safety and environment a goal of at least equal importance to profitability and productivity;

• protect the health and welfare and promote the occupational safety of all persons directly or indirectly involved in its operations;

• pursue excellence in behavior and continuous improvement in occupational health and safety and accident prevention, in environmental protection and preservation;

• ensure the centrality of the individual by fostering consultation the participation of workers and other stakeholders and ensure the sharing of experience and knowledge;

• design, implement and manage each activity taking into account the need to ensure the protection of the health and safety of employees and third parties, the protection of the environment and public safety;

• promote the use of natural gas in a safe, efficient and environmentally friendly manner; and

• train staff and exchange information and knowledge, which are considered fundamental tools for achieving health, safety, environmental and public safety objectives, with a view to continuous improvement.

In view of the above, we intend to pursue the above principles by committing to the following aims:

• manage activities in full compliance with current legislation and signed voluntary standards and agreements as well as national and international best practices, ensuring compliance obligations and assessment of risks and opportunities, consistent with the Code of Ethics, Corporate Model 231 and all HSE Policy regulations;

• ensure that each worker is aware of, responsible for, and participates in the company’s efforts to manage the aspects of occupational health and safety and environmental protection and quality assurance related to their activities, with the understanding that the responsible behavior of each person is a prerequisite for the success of the entire system;

• ensure the protection of workers’ health and safety by adopting the most advanced principles, national standards, organizational solutions, adopting safe and healthy working conditions, using materials and equipment with the least risk to health, safety and the environment for the elimination of hazards and minimization of risks, with a view to the prevention of accidents, injuries, occupational diseases and emergency situations;

• implement every effort in organizational, operational and technological terms to prevent water, air and soil pollution, minimizing, where technically possible, environmental impacts related to the company’s activities, with particular reference to the control of air emissions, water discharges, waste management, energy saving and recovery;

• support the conservation of natural resources with actions aimed at effective and efficient use of energy, minimizing the consumption of energy, water, and materials, also in the interest of future generations;

• involve and consult workers, including through their health, safety and environmental representatives;

• use qualified suppliers and promote their development according to the principles of this policy, committing them to maintain behavior consistent with it even when they operate outside the company;

• conduct periodic system audits, inspections, audits, and reviews to analyze performance, contextual factors, stakeholder needs, risks and opportunities, objectives, programs, and policy to assess their effectiveness and take consequent action to pursue the goal of continuous improvement; and

• putting in place actions to prevent any intentional or negligent event that may cause actual or potential harm to persons and tangible and intangible assets of the company.

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Government Funding and Other Forms of Support

Conventional Natural Gas

Recently, due to the increased importance of energy security, the Italian Government adopted measures to promote domestic production and accelerate the increase of local gas production. An example of this policy is the 2023 Energy Decree (Law Decree 181/2023), which simplified into a single integrated administrative procedure any new concessions, extensions and modifications of existing concessions, the authorizations for production concessions, and the execution and review of environmental assessments. The single integrated administrative procedures target feedback within three months from the date of submission for applicants who have expressed interest in entering into natural gas supply contracts with the Italian government. In addition, Legislative Decree 135/2018, which introduced a plan to limit the areas where E&P activities may be undertaken, was voided by the Rome Administrative Tribunal in February 2024.

Renewable Natural Gas

Increasingly, the security of supply has become critical for the EU and Italy, creating a more favorable regulatory environment for local production of fossil energy, especially gas and renewable energy. The National Recovery and Resilience Plan (NRP), part of the Next Generation Europe program, was launched by the EU to balance the economic and social consequences of the COVID-19 pandemic. For Italy, the PNRR allocated €191.5 billion, including nearly €60 billion earmarked to the energy transition, including the development of biomethane.

Decree 340 of September 15, 2022 implemented new incentives around biomethane. Specifically, that biomethane production will be supported and incentivized through a capital subsidy of up to 40% for the upgrading of existing biogas facilities and the construction of new biomethane facilities, as well as a new 15-year subsidized tariff (price floor). These incentives were further increased by Law 136 on October 9, 2023, to account for cumulative average inflation. Further, DM No. 224, issued in July 2023, expanded the sectors to which Guarantees of Origin can be sold, including industry and heating.

Customers

As of December 31, 2024 and December 31, 2023, we have not generated any revenue from our operations other than from sales of electricity from two renewable gas assets that were purchased in July 2024. We anticipate that our customers will largely consist of Shell as well as industrial, power generation and residential customers throughout Italy and into the southern EU.

Competition

Conventional Natural Gas

Competition in the Italian E&P industry is limited to a relatively small number of licensed operators. Historically led by the former Italian NOC Eni (who has transformed itself into an international company), the industry over the past approximately ten years has come to be dominated by smaller public and private companies. In the Po Valley, overlapping with AleAnna, direct competitors include Energean PLC, Società Padana Energia, Po Valley Energy, and Pengas Italiana Srl. Royal Dutch Shell and Total remain significant producers of the legacy producing oils fields (principally Val’d Agri and Tempa Rossa in the southern part of the country) but are no longer active in Italian oil and gas exploration activities.

Renewable Natural Gas

Competition in this rapidly emerging market space is not yet well-organized in Italy. While some private equity groups are beginning to explore Italian renewable natural gas opportunities, the landscape remains fragmented. However, in the recent past, Eni and midstream operator SNAM attempted early entry by acquiring approximately 50 operational anaerobic digesters. Eni has since sought at least partial divestment of these assets and an exit from the biomethane production market in order to focus on other Renewables initiatives. Other major energy firms such as Royal Dutch Shell, BP, and Total have focused their early efforts on attempts to lock up longer-term biomethane marketing agreements but have yet to actively invest in biomethane production operations.

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Active investors in the facility acquisition and operations space are principally characterized in two groups: companies such as AleAnna and asset management firms like Goldman Sachs Assets Management and Lazard.

In addition, a number of EPC contractors offer design, construction, and turn-key operations services for biomethane facilities. Examples include IES Biogas (a SNAM company) and BTS Biogas. However, to date, these players have not competed as full owner-operators.

Raw Materials and Suppliers

Conventional Natural Gas

AleAnna has access to numerous sources of oilfield supplies and services in Italy, and we will use specific vendors on each project based upon a combination of availability, cost-effectiveness, availability of specific equipment, and performance reputation. Examples of vendors we have used in the past and are likely to use for future operations include:

Category |  | Vendors
Drilling rigs and laborers |  | Pergemine SpA, LP Drilling
Well logging and evaluation |  | Schlumberger, Baker Hughes
Well casing and cementing services |  | Schlumberger, Baker Hughes
Drill bits and downhole equipment |  | Schlumberger, Baker Hughes
Plant engineering and construction |  | Saipem, Demont Srl
Seismic acquisition |  | Schlumberger, Doland Geophysical
Purchase of existing Seismic |  | Eni, CGG
Seismic processing |  | Tricon, CGG
Seismic and well log interpretation software |  | Schlumberger, S&P Global (IHS Markit)
Drilling rigs and laborers |  | Pergemine SpA, LP Drilling

Renewable Natural Gas

AleAnna has had discussions with, and in some cases, entered into agreements with providers of investment opportunities, project developers, commodity traders for the supply of agricultural waste, bio-digester manufacturers, upgrading facility suppliers, and major marketing groups. Examples of vendors we are currently engaged with include:

Category |  | Vendors
— Investment opportunities |  | VLF Srl
— Project developers |  | Renove Srl
— Commodity traders |  | Rivecom
— Bio-digester manufacturers |  | Rota Srl
— Biomethane upgrading facilities |  | Prodeval Srl
— Marketing groups |  | Shell Energy Europe

Human Capital Resources

As of December 31, 2024, we had seven full-time employees and engaged six contractors on a part-time basis, and one contractor on a full-time basis. Our workforce is concentrated in Texas and Italy (principally in the Rome and Milan areas). The working relationship for employees in Italy is regulated by the pertaining collective work agreement, which provides for the basic standard conditions applicable depending on the employee’s level of seniority. In Italy, levels of welfare and social security are guaranteed. We have a seasoned leadership team with over 100 years of cumulative experience in the conventional and renewables industry. Our employees are a key factor to our strategies and we are committed to maintaining a workplace free of any discrimination and to establishing appropriate measures for health and safety at work, as well as for professional development, equal opportunities and work-life balance. Our management team places significant focus and attention on matters concerning our human capital assets and is focused on expanding our diversity, enhancing capability development, and succession planning. Accordingly, we regularly review employee development and succession plans for each of our functions to identify and develop our talent pipeline. To date, we have not experienced any work stoppages and consider our relationship with our employees to be in good standing.

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Corporate Information and Facilities

AleAnna is a corporation incorporated under the laws of Delaware. Our headquarters is currently in Dallas, Texas, and houses our US-based management team and certain support individuals. Our Italian management team is housed in Rome, Italy-based offices. Our website is located at www.aleannainc.com.

Leasing our facilities gives us the flexibility to expand or reduce our office space as appropriate. We believe our current facilities are adequate for our current operating needs, and we anticipate that we will have access to other facilities, through future contractual arrangements, for development, testing, and production.

We have completed or partially completed production facilities for conventional natural gas at the Longanesi field (near Lugo, Italy), the Gradizza Field (near Copparo, Italy), and the Trava Field (near Ostellato, Italy). These conventional gas facilities do not require human intervention on a 24/7 basis and thus house no field staff. We have existing facilities and/or land under construction for renewable natural gas at the Campagnatico plant (Tuscany) and, following successful acquisition, in short order, we expect to begin upgrading construction on the Fattoria Delle Jersey plant (near Milan).

Legal Proceedings

We do not have any claims, lawsuits or proceedings currently pending against us, individually or in the aggregate. However, from time to time, we may be subject to various claims, lawsuits and other legal and administrative proceedings that may arise in the ordinary course of business. Some of these claims, lawsuits and other proceedings may involve highly complex issues that are subject to substantial uncertainties, and could result in damages, fines, penalties, non-monetary sanctions or relief. We recognize provisions for claims or pending litigation when we determine that an un-favorable outcome is probable and the amount of loss can be reasonably estimated. Due to the inherent uncertain nature of litigation, the ultimate outcome or actual cost of settlement may materially vary from estimates.

Blugas Settlement

On May 28, 2024, we entered into the Blugas Settlement Agreement with Blugas, regarding Blugas’ retained interest in the physical volumes extracted from the Longanesi field. We contested the existence of Blugas’ right to receive the Blugas ORRI. Under the terms of the Blugas Settlement Agreement, we agreed to pay Blugas approximately €5 million, plus an additional €1.1 million in applicable VAT (a total of approximately $6.6 million in U.S. Dollars). In exchange for such payment, Blugas agreed to irrevocably waive, among other things, the Blugas ORRI and release us from any future liability related to the Blugas ORRI. As a result of the transactions contemplated by the Blugas Settlement Agreement, our 33.5% working interest in the Longanesi field is now unencumbered except for normal government royalties (10%). The Blugas Settlement Agreement was accounted for as an acquisition of the Blugas ORRI claim with a corresponding increase to the expected future cash flows from our reserves. Our year-end December 31, 2023 reserve quantities included the 20% of 350 million standard cubic meters (approximately 2,472 106ft3) allocable to the Blugas ORRI in its proved gas reserves. However, the required payments to Blugas associated with the sale of such quantities were reflected as cash outflows (costs) as if such amounts were paid to Blugas.

Following settlement, our year-end December 31, 2024 reserve quantities continue to include the 20% of 350 million standard cubic meters (approximately 2,472 106ft3), however, the previously required payments to Blugas associated with the sale of such quantities are no longer reflected as cash outflows (costs) as if such amounts were paid to Blugas. As the cash outflows (costs) are no longer reflected as if paid to Blugas, such amounts are reflected in our December 31, 2024 reserve report as allocable to our unencumbered 33.5% working interest.

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MANAGEMENT

The following table sets forth information about our executive officers as of April 16, 2025:

Name |  | Age |  | Position(s)
William K. Dirks |  | 67 |  | Executive Director
Marco Brun |  | 59 |  | Chief Executive Officer
Tristan Yopp |  | 39 |  | Chief Financial Officer and Secretary
Charles Roscopf |  | 36 |  | Chief Accounting Officer and Treasurer

The following table sets forth information about our directors as of April 16, 2025:

Name |  | Age |  | Position(s)
Graham van’t Hoff |  | 63 |  | Director and Chairman of the Board
William K. Dirks |  | 67 |  | Director
Marco Brun |  | 59 |  | Director
Duncan Palmer |  | 59 |  | Director
Curtis Hébert |  | 62 |  | Director

Executive Officers

William (“Bill”) K. Dirks, 67, Mr. Dirks has served as Executive Director and as a member of the Board of Directors for AleAnna since the closing of the Business Combination. Prior to the closing of the Business Combination, Mr. Dirks served as Executive Chairman for AleAnna Resources, LLC and AleAnna Energy since 2015. Since 2015, Mr. Dirks has also served as Chairman and CEO of 1852797 Alberta ULC, and CEO of Nautilus Resources LLC (a wholly owned Bluescape subsidiary which, through Nautilus, is a significant shareholder in AleAnna, and 1852797 Alberta ULC). Mr. Dirks has served in these roles as an independent executive contractor and his responsibilities for the group include pursuing, acquiring, and developing oil and gas licenses in the US, Canada, and Italy. He is also responsible for strategy design, transaction negotiation, and overall day-to-day management of the companies, including technical and operational execution. Mr. Dirks has more than 43 years of exploration and production operating experience worldwide, including asset acquisitions, design and management of seismic operations, drilling and completions programs, and management of production operations. Mr. Dirks has a track record of creating value in the upstream E&P sector through senior management and fund-raising experience at publicly and privately held companies. Prior to his current postings, from 2010 – 2014, Mr. Dirks served as President and Chief Operating Officer of Sonde Resources Corporation, a publicly-traded (TSX and NYSE) global E&P company with operations in Western Canada and Northern Africa. At Sonde, Mr. Dirks was responsible for strategy, asset acquisitions, and overall technical and operational execution. While at Sonde, Mr. Dirks successfully assembled over 250,000 sweet-spot acres in the Duvernay, Montney, and Wabamun plays. Prior to Sonde, from 2006 – 2010, Mr. Dirks was Co-Founder and Managing Partner of Tecton Energy LLC, a privately held E&P company focused on U.S. and Canadian onshore unconventional resource plays. In his role at Tecton Energy, Mr. Dirks was responsible for strategy, asset acquisitions, development, and operational execution. At Tecton Energy, Mr. Dirks purchased and monetized exploration positions in excess of 500,000 acres in a three-year period. Prior to Tecton Energy, from 2002 – 2006, Mr. Dirks was President of Samson Canada, a large family-owned E&P company with approximately 250 employees/contractors, 200 MMcf/d production, 200 new wells annually, and 1MM acres of unconventional resource and tight gas holdings in Alberta and British Columbia. In his role at Samson, Mr. Dirks was responsible for technical and operational execution. Further, Mr. Dirks held a series of positions at Shell Oil Company from 1981 – 1999, ultimately serving as President and CEO of Shell Technology Ventures (1996), and as U.S. Onshore exploration manager (1992). While CEO of Shell Technology Ventures, Mr. Dirks raised $120 million, implemented a partnership with Beacon Group, and launched five start-ups in the fields of drilling, re-completion, processing, and remediation. While serving as an exploration manager, Mr. Dirks was responsible for annual exploration and production capital development programs in excess of $100 million. Mr. Dirks earned a Bachelor of Science in geology and a Master of Science in civil engineering from Iowa State University, and is a Henry Crown Fellow of the Aspen Institute.

Marco Brun, 59, has served as our Chief Executive Officer and as a member of our Board of Directors since the closing of the Business Combination. Prior to the closing of the Business Combination, Mr. Brun has been employed by, and has served, as the CEO and sole director of AleAnna Italia S.p.A. since September 2022. Mr. Brun’s current responsibilities include advancing AleAnna’s conventional natural gas exploration and production developments

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(including both the Longanesi field and AleAnna’s other conventional prospects). Mr. Brun is also responsible for acquiring, integrating, and overseeing operation of AleAnna’s renewable natural gas acquisition and development projects. Prior to employment with AleAnna, Mr. Brun served the company as independent executive contractor from March 2021 through August 2022 where he provided strategic consulting around business development, regulatory affairs, and operational execution. Previously, from July 2018 to February 2021, Mr. Brun served as Vice President at Assomineraria Confindustria Industry Association, acting as a lobbyist for hydrocarbons and geothermal energy. During the same period, Mr. Brun was a Supervisory Board Member at the Confindustria Energia Industry Association, an Executive Committee Member at Aspen Institute Italy (from June 2019 to February 2021) and a Non-Executive Board Member at the British Embassy in Italy from October 2010 to February 2021. In these roles, Mr. Brun coordinated with industry executives and government representatives to improve dialogue, educate, and enhance conversations around energy and economic development in Italy. One of Mr. Brun’s most notable tenures was at Shell plc, where he held several key positions. From December 2009 to February 2021, Mr. Brun was Chief Executive Officer Upstream and Country Chair Italy and Adriatic Countries at Shell, as well as CEO and President of the Board of Directors of Shell Italia E&P S.p.A. with revenues exceeding $2 billion and CFFO of over $500 million. His responsibilities included overseeing operational execution of business lines as well as managing Shell’s reputation, government relations, strategy, and business delivery across various sectors and European geographies. Mr. Brun played a key role in lobbying activities, sponsorships with Ferrari and Ducati, and led significant transactions such as the divestment of the Italian retail gas network and the acquisition of Sonnen in Italy. Previously, Marco was also the General Manager of Gas & Power Italy and France at Shell from September 2006 to December 2009, where he oversaw operational execution, strategy, and spearheaded market entries and managed substantial projects such as the re-gas terminal development in France and Italy. Mr. Brun’s earlier career included roles in business development, and sales and marketing, where he consistently delivered outstanding performance, managed and negotiated significant contracts, acquired assets, and developed new lines of business. Mr. Brun stands as a seasoned senior executive with a distinguished career, spanning nearly three decades in the energy sector. Mr. Brun has garnered experience across downstream, midstream, and upstream Oil, Gas, Power, and Renewables sectors. Mr. Brun’s career has seen him operate in diverse geographies, including Italy, USA, Canada, UK, Netherlands, Turkey, Spain, Portugal, France, Greece, Slovenia, Croatia, and Albania, allowing him to seamlessly adapt to various economic environments. Since 2016, Mr. Brun has also contributed to academia through his ongoing tenure as a Visiting Professor at Sciences Po University, Paris School of International Affairs. Here, Mr. Brun imparts his knowledge on “Industrial Energy Transitions” within the International Energy Transitions Master program. Mr. Brun holds a Master’s Degree in Business Administration from the University of Bergamo and has completed additional courses at prestigious institutions such as Bocconi School of Management and Harvard Business School. Throughout his career, Marco Brun has demonstrated an unwavering commitment to excellence, strategic vision, and the ability to create significant value in diverse and challenging environments. His leadership and expertise continue to influence the European energy industry.

Tristan Yopp, 39, has served as our Chief Financial Officer since the closing of the Business Combination. Prior to the closing of the Business Combination, Mr. Yopp served as the acting Chief Financial Officer of AleAnna since July 2021 and as a Director of AleAnna Resources, LLC and AleAnna Energy, LLC since 2018. Since September 2018, Mr. Yopp has been employed as a Vice President by Bluescape Energy Partners LLC and has also served as Chief Financial Officer of Bluescape Resources Company LLC (collectively, “Bluescape Group”). At Bluescape Group, Mr. Yopp is an investment team member for two institutional private equity funds and is responsible for investment underwriting, due diligence, interim CFO, and portfolio analytical and performance management support. Mr. Yopp is also responsible for managing Bluescape Group’s liquid portfolios, leading the quarterly valuation process, facilitating investor relations and fundraising, and overseeing back-office processes, including compliance, audits, tax strategy, and financial reporting. While at Bluescape Group, Mr. Yopp has contributed to raising and deploying approximately $500 million into private equity investments and has executed hundreds of millions of liquid security trading programs. Mr. Yopp was also instrumental in the de-SPAC of one of Bluescape Group’s portfolio companies, Verde Clean Fuels, Inc., a publicly traded clean fuels technology company. From October 2020 through November 2023, while employed by Bluescape Energy Partners LLC, Mr. Yopp also served as Chief Financial Officer and Chief Governance Officer of Bluescape Opportunities Acquisition Corp. (NYSE: BOAC), a special purpose acquisition company sponsored by Bluescape Group. Through his BOAC role, Mr. Yopp was responsible for investment origination and evaluation, diligence, transaction design, governance processes, and back office administration including compliance and financial reporting. Prior to Bluescape Group, from July 2011 – September 2018, Mr. Yopp held a series of finance and accounting roles with Celanese ultimately serving as Sr. Manager Financial Planning & Analysis. While at Celanese, Mr. Yopp was responsible for financial oversight, strategy design, and operational execution for three international business lines exceeding $500 million in aggregate revenue and contributed to capacity expansion

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decisions, acquisition integration, enhanced performance reporting, and operational optimization within the Celanese portfolio. Additionally, while at Celanese, Mr. Yopp was Manager of SEC Reporting where he oversaw financial reporting, including valuation and reporting for $4 billion in global pension assets. In his roles at Celanese, Mr. Yopp contributed to significant shareholder value creation through execution of global restructuring plans and provided financial reporting and technical accounting support for multiple transactions, including $800 million of acquisitions and over $2 billion of public debt offerings. Prior to Celanese, from September 2008 to July 2011, Mr. Yopp worked in KPMG’s external audit practice where he provided professional audit services and was the lead senior associate on the CenturyLink engagement during CenturyLink’s aggregate $24 billion Embarq and Qwest acquisitions. Mr. Yopp earned a Bachelor of Science in Accounting and Business Administration from Centenary College, where he graduated summa cum laude, and a Master’s in Business Administration from The University of Texas. Mr. Yopp is a Certified Public Accountant.

Charles Roscopf, 36, has served as our Chief Accounting Officer since the closing of the Business Combination. Prior to the closing of the Business Combination, Mr. Roscopf served as the acting Chief Accounting Officer of AleAnna and as a Director of AleAnna Resources, LLC since November 2023. Since October 2023, Mr. Roscopf has been employed as a Vice President by Bluescape Energy Partners LLC and has also served as Controller of Bluescape Resources Company LLC. In these roles, he is responsible for overseeing accounting, tax compliance and financial reporting for Bluescape Group and its subsidiaries, including AleAnna. Prior to joining Bluescape Group, From October 2019 to September 2023, Mr. Roscopf was a Controller at Beneficient, a publicly traded niche provider of liquidity to holders of alternative assets. While at Beneficient, he was involved in SEC reporting, general and technical accounting, treasury functions, and played a key role in the company’s 2023 de-SPAC transaction. From May 2017 to October 2019, Mr. Roscopf was a Vice President at Hilltop Holdings, a publicly traded Texas-based financial services company, where he managed SEC reporting, bank regulatory reporting, stock compensation accounting, and technical accounting. Between September 2011 and May 2017, Mr. Roscopf worked at EY focusing on public and private audit clients in the real estate industry and other sectors, including healthcare, oil and gas, and financial services. During his time at EY, he participated in a global rotation program and spent the summer of 2015 in São Paulo, Brazil where he shared best practices with local audit teams. Mr. Roscopf holds a Bachelor of Science in Business Administration in Accounting, graduating cum laude, and a Master of Accountancy from the University of Arkansas. Mr. Roscopf is a Certified Public Accountant in the State of Texas.

Non-Executive Directors

Graham van’t Hoff, 63, has served as a member of the Board of Directors of AleAnna since the closing of the Business Combination. Mr. van’t Hoff served as the chief executive officer of Shell Chemicals from January 2013 to June 2019. During his role as CEO of Shell Chemicals, Mr. van’t Hoff oversaw significant global growth in the revenue and profit of Shell’s chemical businesses, with revenues exceeding $24 billion. Mr. van’t Hoff also oversaw the construction of two new petrochemical complexes and executed asset rationalization programs. Mr. van’t Hoff was also previously executive vice president of Shell Alternative Energies from January 2012 to December 2012. During his role as EVP of Shell Alternative Energies Mr. van’t Hoff was responsible for Shell’s emerging biofuels and hydrogen businesses including Raizen, a Brazilian biofuels company. Mr. van’t Hoff also served as a board member of Shell International Petroleum Co. from 2014 to 2017 and chairman of Shell UK Limited from March 2011 to December 2012. He has extensive board experience on several global joint ventures, including Infineum, a joint venture between Shell and ExxonMobil focused on the formulation, manufacturing and marketing of petroleum additives for lubricants and fuels, as well as chairman of CSPC (CNOOC Shell Petrochemicals Co), one of the largest Chinese petrochemical companies. During his tenure at Shell, Mr. van’t Hoff’s 35 years of experience spans multiple segments of the energy and chemical sectors from upstream through refining, marketing and trading, P&L leadership, strategy, government relations, technology and IT. Mr. van’t Hoff’s extensive international business experience includes appointments to the boards and executive committees of multiple international chemical industry associations, including ACC (the American Chemistry Council), CEFIC (the European Chemical Industry Association), and ICCA (the International Council of Chemical Associations). He was also a founding member of the Alliance to End Plastic Waste, formed in 2019, which gained $1.5 billion of funding commitments in its first year of formation, and is on the Oxford University Chemistry Development Board. Mr. van’t Hoff currently serves on several boards, as described below, and has participated in consulting work in the energy and chemical industry since June 2019. He also serves on the North American Advisory Board for Air Liquide, and on the board of the privately-owned, commercial solar farm developer and operator, Silicon Ranch Corporation. Mr. van’t Hoff has served as a director of Verde Clean Fuels, Inc., a publicly traded clean fuels technology company since February 2023. Additionally, Mr. van’t Hoff previously

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served as an independent director, a member of the audit committee, the chairman of the nominating committee and a member of the compensation committee of Bluescape Opportunities Acquisition Corp. from September 2020 through November 2023. He has also served as a director of 5E Advanced Materials, Inc. since October 2022 and Metals Acquisition Limited since November 2023. Mr. van’t Hoff earned a Master’s degree in Business Management, with Distinction, from Manchester Business School and a Master’s degree in Chemistry from the University of Oxford. We believe Mr. van’t Hoff’s extensive energy, financial and operational experience qualifies him to serve on the Board.

Duncan Palmer, 59, has served as a member of the Board of Directors of AleAnna since the closing of the Business Combination. Mr. Palmer is the former chief financial officer of Cushman & Wakefield, a leading global real estate services company and served in this position from November 2014 to February 2021. During his tenure at Cushman & Wakefield, Mr. Palmer oversaw 700 staff across 60 countries and was responsible for all aspects of the company’s financial operations, planning and analysis, internal audit, taxation, treasury, investor relations and information technology. As chief financial officer, Mr. Palmer led Cushman & Wakefield’s IPO and oversaw all aspects of the company’s financial operations, including multiple corporate functions from treasury and investor relations to tax and internal audit. From 2012 to 2014, Mr. Palmer served as the chief financial officer of RELX, a global provider of information-based analytics and decision tools. During his tenure at RELX, Mr. Palmer oversaw 1,800 staff globally and was responsible for all aspects of the company’s financial operations, planning and analysis, internal audit, taxation, treasury, investor relations and procurement. From 2007 to 2012, Mr. Palmer served as the chief financial officer of Owens Corning, a global manufacturer of building materials and fiber glass reinforcements. During his tenure at Ownes Corning, Mr. Palmer oversaw 500 staff globally and was responsible for all aspects of the company’s financial operations, planning and analysis, audit, taxation, treasury, investor relations and sourcing. Mr. Palmer was also responsible for the company’s corporate strategy, corporate development, and mergers and acquisition activities. Mr. Palmer currently sits on the board of Oshkosh Corporation, a vehicle and equipment supplier with global operations, where he has served as a member of the board since 2011 and has been chairman of the audit committee since 2019. Mr. Palmer has also served as a director of Verde Clean Fuels, Inc., a publicly traded clean fuels technology company since February 2023. Mr. Palmer also previously served as an independent director, chairman of the audit committee, a member of the nominating committee and a member of the compensation committee of Bluescape Opportunities Acquisition Corp. from October 2020 through November 2023. Mr. Palmer has extensive financial operations, transactional, and business development knowledge and experience through previous chief financial officer appointments at Cushman & Wakefield, RELX, Owens Corning and as a senior finance executive at Royal Dutch Shell. Mr. Palmer’s extensive international business experience includes leadership of finance organizations ranging in size from 500 to 2,000 employees and encompasses multi-billion dollar capital allocation programs, merger integrations, debt offerings and share repurchase programs. His experience spans many segments of the energy, lubricants, materials, information services and real estate services sectors. Mr. Palmer also has deep transactional and business development experience, having overseen mergers and acquisitions execution, as well as corporate strategy. Mr. Palmer earned a Master’s degree of Business Administration from the Stanford Graduate School of Business and a Master’s degree from St. John’s College Cambridge (UK). He is a Fellow of the Chartered Institute of Management Accountants (UK). We believe Mr. Palmer’s extensive operational and financial experience qualifies him to serve on the Board.

Curtis Hébert, Jr., 62, has served as a member of the Board of Directors of AleAnna since the closing of the Business Combination. Mr. Hébert is currently a partner with the Brunini Law Firm, where he has advised energy companies and corporations throughout the globe on numerous matters, including building accountability and transparency into corporate governance, improving the quality of regulatory filings, reporting and relationships, and executing complex, structured regulatory settlements since July 2012. Previously, Mr. Hébert served as chief executive officer of Lexicon Strategy Group, an energy, finance and regulatory law advisory firm, from August 2010 to July 2012. Mr. Hébert is also a former executive vice president for Entergy Corporation, where he served from September 2001 to July 2010. During his time at Entergy, Mr. Hébert was responsible for Corporate Governance and led regulatory strategy and regulatory compliance for Entergy’s regulated operating companies. Mr. Hébert is also the former Commissioner and Chairman of the Federal Energy Regulatory Commission, where he served from November 1997 to September 2001. He also served as a visiting scholar with the Bipartisan Policy Center in Washington, where he co-chaired the Energy Reliability Task Force and the Cybersecurity Task Force. Mr. Hébert has broad and deep experience in multiple segments of the energy sector, spanning exploration and production, natural gas transportation, electric generation and distribution, chemicals, and mining. He brings a thorough knowledge of national and international energy markets, policy, and regulatory processes. Mr. Hébert also spent years in the telecommunications, transportation, and water/sewage sector on regulatory filings and administrative hearings.

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Mr. Hébert has served as a director of Verde Clean Fuels, Inc., a publicly traded clean fuels technology company since February 2023. Mr. Hébert also previously served as an independent director, a member of the audit committee, a member of the nominating committee and the chairman of the compensation committee of Bluescape Opportunities Acquisition Corp. from September 2020 through November 2023. Mr. Hébert earned a Juris Doctorate from the Mississippi College School of Law and a Bachelor’s degree from the University of Southern Mississippi. We believe Mr. Hébert’s extensive experience in corporate governance and regulatory matters qualify him to serve on the Board.

Director Independence

Nautilus and its affiliates under common control beneficially own a majority of the voting power of all outstanding shares of our common stock. As a result, AleAnna is a “controlled company” within the meaning of the Nasdaq Listing Rules. Under the Nasdaq Listing Rules, a company of which more than 50% of the voting power for the election of directors is held by an individual, group or another company is a “controlled company” and may elect not to comply with certain corporate governance standards, including the requirements that a majority of its board of directors consist of independent directors. Notwithstanding the availability of such exemptions, a majority of AleAnna’s current Board members qualify as independent under applicable Nasdaq rules.

Nasdaq rules generally require that independent directors must comprise a majority of a listed company’s board of directors. Under the rules of Nasdaq, a director generally only qualifies as an “independent director” if the director and, in the opinion of that company’s board of directors, that person does not have a relationship that would interfere with the exercise of independent judgment in carrying out the responsibilities of a director, subject to certain “bright-line” determinations that would result in a director not being deemed independent for purposes of Nasdaq rules. Based upon information requested from and provided by each proposed director concerning his or her background, employment and affiliations, including family relationships, the Board has determined that Mr. van’t Hoff, Mr. Palmer and Mr. Hébert are “independent” as that term is defined under the applicable rules and regulations of the SEC and the listing requirements and rules of Nasdaq.

Board Leadership Structure

Our Board maintains flexibility to select an executive or independent chairperson of the Board, and to consider designating a lead independent director in the event that an executive is serving in the role of Board chair. Graham van’t Hoff serves as chairperson of the Board and is responsible for, among other matters, serving as a liaison between the Board and the CEO, approving Board meeting agendas, facilitating communication of annual Board evaluation feedback, and participating with the compensation committee in the annual CEO performance evaluation.

We believe that this leadership structure will allow our CEO to focus his time and energy on managing our business, while our Chairperson provides time and attention to board oversight and governance. However, we believe that no single leadership model is right for all companies and at all times, and the Board will review its leadership structure as appropriate to ensure it continues to be in the best interests of AleAnna and its stockholders. The Board may adjust its Board leadership structure based on circumstances existing from time to time and based on criteria that are in the best interests of AleAnna and its stockholders, including the composition, skills, diversity and experience of the board and its members, specific challenges faced by AleAnna or the industry in which it operates, and governance efficiency.

Controlled Company Exemption

The Company is considered a “controlled company” under the rules of the Nasdaq Capital Market. Under the Nasdaq Listing Rules, a company of which more than 50% of the voting power for the election of directors is held by an individual, group or another company is a “controlled company” and may elect not to comply with certain corporate governance standards, including the requirements (i) that a majority of its board of directors consist of independent directors, (ii) that its board of directors have a compensation committee that is composed entirely of independent directors with a written charter addressing the committee’s purpose and responsibilities and (iii) that director nominees must either be selected, or recommended for the board’s selection, either by independent directors constituting a majority of the board’s independent directors in a vote in which only independent directors participate, or a nominating and corporate governance committee comprised solely of independent directors with a written charter addressing the committee’s purpose and responsibilities. For at least some period, the Company may utilize these exemptions, and you may not have the same protections afforded to stockholders of companies that are subject

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to all of these corporate governance requirements. If the Company ceases to be a “controlled company” and its shares continue to be listed on the Nasdaq Capital Market, the Company will be required to comply with these standards and, depending on the Board’s independence determination with respect to its then-current directors, the Company may be required to add additional directors to its board in order to achieve such compliance within the applicable transition periods.

The Board’s Risk Oversight Role

Our Board oversees risk related to the Company and its business as a whole, including its strategy, business performance, capital structure, management selection, compensation programs, stockholder engagement, corporate reputation, cybersecurity and privacy matters, and regulatory risks. Our Board discharges various aspects of its oversight responsibilities through its standing committees, which will in turn report to the Board regularly regarding their activities. We will evaluate risks over the short-, medium-and long-term horizons.

Committees of the Board of Directors

Our Board maintains a standing audit committee (“Audit Committee”) and a standing compensation committee (“Compensation Committee”), but does not currently maintain a nominating/governance committee based upon the exceptions from the Nasdaq Listing Rules for “controlled companies.” Our Board has overall responsibility for the selection of candidates for nomination or appointment to our Board. The composition of each committee is set forth below.

Audit Committee

The Audit Committee’s primary responsibilities include, among other things:

• overseeing management’s establishment and maintenance of adequate systems of internal accounting and financial controls;

• the effectiveness of our legal and regulatory compliance programs;

• overseeing our financial reporting process, including the filing of financial reports; and

• selecting independent auditors, evaluating their independence and performance and approving audit fees and services performed by them.

Our Audit Committee has been established in accordance with Section 3(a)(58)(A) of the Exchange Act and consists of Duncan Palmer, Graham van’t Hoff, and Curtis Hébert, each of whom are independent directors and are “financially literate” as defined under the Nasdaq listing standards. Duncan Palmer serves as chairman of the Audit Committee. Our Board has determined that Duncan Palmer qualifies as an “audit committee financial expert,” as defined under rules and regulations of the SEC.

Compensation Committee

The Compensation Committee’s responsibilities include, among other things:

• ensuring that our executive compensation programs are appropriately competitive, supporting organizational objectives and stockholder interests and emphasizing pay-for-performance linkage;

• evaluating and approving compensation and setting performance criteria for compensation programs for our chief executive officer and other executive officers; and

• overseeing the implementation and administration of our compensation plans.

Our Compensation Committee consists of Bill Dirks, Graham van’t Hoff, and Curtis Hébert, each of whom is an independent director. Curtis Hébert serves as chairman of the Compensation Committee.

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Code of Ethics and Business Conduct

Our Board has adopted a Code of Business Conduct and Ethics for our directors, officers, employees and certain affiliates in accordance with applicable federal securities laws, a copy of which is available on our website at www.aleannainc.com under “Investor Relations.” We will make a printed copy of the Code of Business Conduct and Ethics available to any stockholder who so requests. Requests for a printed copy may be directed to our Chief Financial Officer, Tristan Yopp at tgyopp@bluescapegroup.com.

If we amend or grant a waiver of one or more of the provisions of our Code of Business Conduct and Ethics, we intend to satisfy the requirements under Item 5.05 of Form 8-K regarding the disclosure of amendments to or waivers from provisions of our Code of Business Conduct and Ethics that apply to our principal executive officer, principal financial officer, principal accounting officer or controller, or persons performing similar functions or any other officer, and that relates to any element of the code of ethics definition enumerated in Item 406(b) of Regulation S-K by posting the required information on our website at www.aleannainc.com.The information on this website is not part of this Registration Statement.

Insider Trading Policy

Our Board has adopted an insider trading policy governing the purchase, sale and/or other dispositions of its securities by directors, officers and certain employees that is reasonably designed to promote compliance with insider trading laws, rules and regulations. Our insider trading policy is available on our corporate website, www.aleannainc.com under “Investor Relations”.

Whistleblower Policy

Our Board has adopted a whistleblower policy to provide employees with a confidential and anonymous method for reporting concerns about the conduct of the Company or employees free from retaliation. Our whistleblower policy is available on our corporate website, www.aleannainc.com under “Investor Relations”.

Compensation Recovery Policy

Our Board has adopted a compensation recovery policy, which provides that in the event the Company is required to prepare an accounting restatement due to noncompliance with any financial reporting requirements under the securities laws or otherwise erroneous data or the Company determines there has been a significant misconduct that causes financial or reputational harm, the Company shall recover a portion or all of any incentive compensation. Our compensation recovery policy is available on our corporate website, www.aleannainc.com under “Investor Relations”.

Limitation of Liability and Indemnification of Directors and Officers

Our Certificate of Incorporation and Bylaws limit a director’s and officer’s liability to the fullest extent permitted under the DGCL; provided, however, that, except in certain circumstances, the Company shall indemnify any such indemnitee in connection with a proceeding (or part thereof) initiated by such indemnitee only if such proceeding (or part thereof) was authorized by the Board. An indemnitee shall also have the right to be paid by the Company the expenses (including attorney’s fees) incurred in appearing at, participating in or defending any such proceeding in advance of its final disposition or in connection with a proceeding brought to establish or enforce a right to indemnification or advancement of expenses under the Bylaws.

The DGCL provides that directors and officers of a corporation will not be personally liable for monetary damages for breach of their fiduciary duties as directors or officers, except for liability:

• for any transaction from which the director or officer derives an improper personal benefit;

• for any act or omission not in good faith or that involves intentional misconduct or a knowing violation of law;

• for a director under Section 174 of the DGCL;

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• for any breach of a duty of loyalty to the corporation or its stockholders; or

• for an officer in any action by or in the right of the corporation.

If the DGCL is amended to authorize corporate action further eliminating or limiting the personal liability of directors or officers, then the liability of the directors and officers will be eliminated or limited to the fullest extent permitted by the DGCL, as so amended.

Delaware law and the Certificate of Incorporation and Bylaws provide that the Company will, in certain situations, indemnify its directors and officers and may indemnify other employees and other agents, to the fullest extent permitted by law. Any indemnified person will also be entitled, subject to certain limitations, to advancement, direct payment, or reimbursement of reasonable expenses (including attorneys’ fees and disbursements) in advance of the final disposition of the proceeding.

In addition, the Company has entered into separate indemnification agreements with each of its directors and officers. These agreements, among other things, are expected to require the Company to indemnify its directors and officers for certain expenses, including attorneys’ fees, judgments, fines and settlement amounts incurred by a director or officer in any action or proceeding arising out of their services as one of its directors or officers or any other company or enterprise to which the person provides services at its request.

The Company also maintains a directors’ and officers’ insurance policy pursuant to which its directors and officers will be insured against liability for actions taken in their capacities as directors and officers. We believe these provisions in the Certificate of Incorporation and Bylaws and these indemnification agreements are necessary to attract and retain qualified persons as directors and officers.

Insofar as indemnification for liabilities arising under the Securities Act may be permitted to directors, officers, or control persons, in the opinion of the SEC, such indemnification is against public policy as expressed in the Securities Act and is therefore unenforceable.

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EXECUTIVE AND DIRECTOR COMPENSATION

This section provides an overview of our executive compensation programs, including a narrative description of the material factors necessary to understand the information disclosed in the summary compensation table below. As an emerging growth company, we have opted to comply with the executive compensation disclosure rules applicable to “smaller reporting companies” as such term is defined in the rules promulgated under the Securities Act, which generally require compensation disclosure for its principal executive officer and its two other most highly compensated executive officers.

Prior to the consummation of the Business Combination, AleAnna Energy was a private company. As a result, the compensation awarded to, earned by, or paid to AleAnna Energy’s directors and named executive officers for the fiscal years ended December 31, 2024 and 2023 were provided by and determined in accordance with policies and practices developed by AleAnna Energy’s board of directors prior to the Business Combination. Following the closing of the Business Combination, the Company’s compensation matters are now reviewed and implemented by our Board and Compensation Committee, as applicable.

During 2024 and 2023, AleAnna Energy only employed one individual serving as an executive officer of AleAnna and that employee, Marco Brun, was employed by AleAnna Energy’s wholly owned Italian subsidiary, AleAnna Italia S.p.A. The other executive officers were either employed or contracted by Bluescape and its affiliates. Except for Marco Brun, AleAnna Energy’s executive officers were either contractors or participated in employee benefit plans sponsored by Bluescape and its affiliates. AleAnna Energy, including AleAnna Italia S.p.A., has not granted any equity awards to either Marco Brun or the executive officers sponsored by Bluescape. During 2024 and 2023, William K. Dirks, Tristan Yopp, and Charles Roscopf provided administrative and support services to AleAnna Energy. William K. Dirks, as a contractor, was compensated pursuant to a Master Services Agreement covering multiple Bluescape entities, including AleAnna Energy. Services provided by Mr. Dirks, Yopp, and Roscopf include insurance, risk management, legal, information technology, purchasing, executive management, accounting, finance, human resources, construction management and database management.

Except for Marco Brun, compensation decisions for AleAnna’s executive officers during 2024 and 2023 were made by Bluescape and its affiliates and any such compensation decisions were not subject to approval by the AleAnna Board. AleAnna’s named executive officers consisted of its principal executive officers as of December 31, 2024, being:

• Marco Brun, Chief Executive Officer; and

• William K. Dirks, Executive Director.

Mr. Brun devotes a substantial portion of his time to AleAnna. AleAnna’s other non-employee executive officers maintain roles with Bluescape and its affiliates and devote time, as needed, directly managing AleAnna’s business and affairs. William K. Dirks receives contractor compensation from AleAnna pursuant to the Dirks Agreement described below, but is not an employee of Bluescape. Further, neither of Messrs. Yopp or Roscopf receive any separate compensation for their services to AleAnna.

Summary Compensation Table

The following table presents information regarding the compensation earned or received by our NEOs for services rendered during the fiscal years ended December 31, 2024 and 2023.

Name and Principal Position |  | Fiscal Year |  | Base Salary ($) |  | Option Awards ($) |  | All Other Compensation ($)(1) |  | Total ($)
Marco Brun |  | 2024 |  | $ | 672,779 |  | — |  | $ | 82,431 |  | $ | 755,210
|  | 2023 |  | $ | 688,255 |  | — |  | $ | 78,086 |  | $ | 766,341
William K. Dirks |  | 2024 |  | $ | 240,000 |  | — |  | $ | — |  | $ | 240,000
|  | 2023 |  | $ | 240,000 |  | — |  | $ | — |  | $ | 240,000

____________

(1) “All Other Compensation” represents fringe benefits, including the monthly lease fee described in the description of the Brun Employment Agreement.

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Narrative Disclosure to Summary Compensation Table

Employment Agreements

Agreement with Chief Executive Officer and Chief Commercial Officer

On September 1, 2022, Aleanna Italia S.p.A., a wholly owned subsidiary of AleAnna Energy, entered into an employment agreement with Mr. Brun effective as of that date (“Brun Employment Agreement”), and pursuant to its terms, Mr. Brun’s base salary is €610,000.00. Mr. Brun is entitled to receive reimbursement for all out-of-pocket expenses incurred by him, which are specifically related to his roles and duties and fall under the guidelines of AleAnna’s expenses policy. The term of the Brun Employment Agreement is permanent.

Mr. Brun receives health insurance through Italy’s national health insurance program (“FASI”) and, pursuant to the Brun Employment Agreement, AleAnna provides insurance for expenses in excess of the coverage provided by FASI. As further described below, Mr. Brun is entitled to the Company’s Medium/Long Term Incentive Plan (the “M/LTIP”, as described below) and may be entitled to certain cash bonuses ranging from €375,000 to €1,125,000 from May 31, 2024, through December 31, 2026. Mr. Brun is also covered by permanent disability and death insurance due to disease, and due to professional or extra professional injuries in the amount specified by the Contratto Collettivo Nazionale Lavoro. In addition, Mr. Brun receives directors’ and officers’ insurance. AleAnna also pays Previndai a contribution equal to 7% of Mr. Brun’s salary. Mr. Brun is entitled to a company vehicle with a monthly lease fee up to €2,500.00 plus applicable VAT, a mobile phone and a laptop with all related expenses to be borne by AleAnna Energy in accordance with AleAnna Energy’s policies.

Mr. Brun is entitled to two years’ base salary to be paid within six months of a Change in Control. “Change in Control” means the first to occur of: (i) the liquidation of AleAnna Energy; (ii) the sale of all or substantially all of the assets of AleAnna Energy; (iii) provided that an initial public offering has not taken place, the date on which AleAnna Energy and its affiliates cease to own, in the aggregate, at least 49% of the beneficial ownership of AleAnna Energy; or (iv) from and after an initial public offering, the date on which AleAnna Energy and its affiliates cease to own, in the aggregate, at least 10% of the beneficial ownership of AleAnna Energy. For avoidance of doubt, the completion of the Business Combination did not constitute a Change of Control under Mr. Brun’s Employment Agreement.

The Brun Employment Agreement also contains customary provisions relating to, among other things, confidentiality and non-solicitation.

Agreement with Mr. Dirks

On July 1, 2022, Aleanna Energy entered into an independent contractor services agreement with Mr. Dirks effective as of that date (“Dirks Agreement”), and pursuant to its terms, Mr. Dirk receives a monthly Contractor Service Fee of $20,000.00 per month. Per the agreement, AleAnna Energy also reimburses Mr. Dirks for certain pre-approved out of pocket expenditures such as travel expenses. Under Dirks Agreement, Mr. Dirks is responsible for all other expenses associated with his services including ancillary benefits such as medical insurance premiums, professional licenses, vehicle insurance expenses, and mobile phone and laptop expenditures.

Medium/Long Term Incentive Plan (“M/LTIP”)

In September 2022, the AleAnna Energy board of directors adopted, and AleAnna Energy’s equityholders approved, the M/LTIP. The following describes the material terms of the M/LTIP.

Cash Bonuses. Certain employees of AleAnna Energy, including Mr. Brun, are entitled to potential cash bonus amounts to be paid based on the completion of certain milestones within the established thresholds. Such payments could result in total payments to employees of AleAnna Energy, including Mr. Brun, ranging from €375,000 to €1,125,000, subject to certain threshold dates.

Performance Metrics. The Company tracks each of the milestones for the M/LTIP package based on AleAnna’s current and future business plans. Based on the metrics and performance indicators outlined in the executive’s compensation package, management has identified that the likelihood of achieving each of these metrics is not probable based on the financial performance as of December 31, 2023, and therefore has not recognized any expense related to the M/LTIP. Any bonus payments are subject to AleAnna Energy’s approval.

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Outstanding Equity Awards at 2024 Fiscal Year End

None.

Director Compensation of AleAnna

AleAnna has not adopted a formal policy or plan to compensate AleAnna’s directors. AleAnna’s directors received no additional compensation for their service as members of the AleAnna Board.

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CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS

In addition to the various agreements and arrangements discussed in the sections titled “Directors, Executive Officers and Corporate Governance” and “Executive and Director Compensation,” the following is a description of each transaction since January 1, 2023 and each currently proposed transaction in which:

• Aleanna has been or is to be a participant;

• the amount involved exceeded or exceeds the lesser of (a) $120,000 or (b) one percent of the average of Aleanna’s total assets at year-end for the fiscal years ended December 31, 2024 and 2023; and

• any of Aleanna’s directors, executive officers or holders of more than 5% of its capital stock prior to the Business Combination, or any immediate family member of, or person sharing the household with, any of these individuals, had or will have a direct or indirect material interest.

Since January 1, 2023, AleAnna (or AleAnna Energy, as applicable) has entered into the following agreements that satisfy the above criteria:

Transactions Entered into in Connection with the Business Combination

A&R HoldCo LLC Agreement

The Company is organized in an “Up-C” structure, such that Company is a publicly listed company that holds a portion of the equity interests in AleAnna Energy through HoldCo. The A&R HoldCo LLC Agreement provides, among other things, that each Class C HoldCo Unit is exchangeable, subject to certain conditions, for one share of Class A Common Stock, and a corresponding share of Class C Common Stock will be cancelled in connection with such exchange, pursuant to and in accordance with the terms of the A&R HoldCo LLC Agreement. The Company is the sole manager of and controls HoldCo, and the Company owns 60.9% of the outstanding equity of HoldCo through Class A HoldCo Units and Nautilus owns approximately 39.1% of the outstanding equity of HoldCo through Class C HoldCo Units. HoldCo owns 100% of the equity interests of AleAnna Energy.

A&R Registration Rights Agreement

On the Closing Date, that certain Registration and Shareholder Rights Agreement, dated December 17, 2021 (the “Registration Rights Agreement”), was amended and restated by the Company, Sponsor, Nautilus, and the John and Susan Wilder Foundation (collectively, the “Registration Rights Holders”) (as amended and restated, the “A&R Registration Rights Agreement”). Pursuant to the A&R Registration Rights Agreement, by February 11, 2025, the Company shall use its commercially reasonable efforts to file with the SEC (at the Company’s sole cost and expense) a registration statement registering the resale of certain securities held by or issuable to the Registration Rights Holders (the “Resale Registration Statement”), and the Company will use its commercially reasonable efforts to have the Resale Registration Statement declared effective as soon as reasonably practicable after the filing thereof. In certain circumstances, the Registration Rights Holders can demand the Company’s assistance with underwritten offerings and block trades, and the Registration Rights Holders are entitled to certain piggyback registration rights. The A&R Registration Rights Agreement does not provide for the payment of any cash penalties by the Company if it fails to satisfy any of its obligations under the A&R Registration Rights Agreement.

A&R Sponsor Letter Agreement

Concurrently with the execution of the Merger Agreement, Swiftmerge, AleAnna and certain affiliates and representatives of Sponsor (including the officers and directors of Swiftmerge) (together with Sponsor, collectively, the “Sponsor Related Parties”) entered into amended and restated letter agreement (the “A&R Sponsor Letter Agreement”) pursuant to which each Sponsor Related Party agreed to, until December 13, 2025, a customary restriction on the sale or transfer of such Sponsor Related Party’s shares of Class A Common Stock. Notwithstanding the lock-up provisions of the A&R Sponsor Letter Agreement, the Sponsor Related Parties may transfer shares of Class A Common Stock to (i) any of Swiftmerge’s officers or directors, any affiliate or family member of any of Swiftmerge’s officers or directors or any members of the Sponsor or any affiliates of the Sponsor; (ii) in the case of an individual, by gift to a member of such individual’s immediate family or to a trust, the beneficiary of which is a member of such individual’s immediate family, an affiliate of such individual or to a charitable organization; (iii) in the case of an individual, by virtue of laws

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of descent and distribution upon death of such individual; (iv) in the case of an individual, pursuant to a qualified domestic relations order; (v) by virtue of the laws of the State of Delaware or the Sponsor’s limited liability company agreement upon dissolution of the Sponsor; or (vi) in the event of Swiftmerge’s liquidation, merger, capital stock exchange, reorganization or other similar transaction which results in all of Swiftmerge’s shareholders having the right to exchange their shares of Swiftmerge Ordinary Shares or Closing Shares (as defined therein) for cash, securities or other property subsequent to Swiftmerge’s completion of the Transactions. Additionally, the lock-up provisions of the A&R Sponsor Letter Agreement may be waived with the consent of Swiftmerge and AleAnna.

Investor Letter Agreements

Additionally, concurrently with the execution of the Merger Agreement, Swiftmerge and Sponsor entered into the Investor Letter Agreements, pursuant to which each investor party thereto has agreed to, among other things, be bound by a customary restriction on the sale or transfer of such investor’s shares of Class A Common Stock until December 13, 2025.

Sponsor Loan

On the Closing Date, that certain unsecured Promissory Note, dated as of September 15, 2023, issued by Swiftmerge in favor of Sponsor, as amended, with an aggregate balance outstanding of $1,527,000 was fully satisfied and discharged in connection with the Business Combination.

Employment Agreements and Indemnification

For a description of AleAnna’s executive and director compensation and management of AleAnna, see “Executive and Director Compensation” and “Directors, Executive Officers and Corporate Governance.”

Limitation of Liability and Indemnification of Directors and Officers

The Certificate of Incorporation and Bylaws limit a director’s and officer’s liability to the fullest extent permitted under the DGCL; provided, however, that, except in certain circumstances, the Company shall indemnify any such indemnitee in connection with a proceeding (or part thereof) initiated by such indemnitee only if such proceeding (or part thereof) was authorized by the Board. An indemnitee also has the right to be paid by the Company the expenses (including attorney’s fees) incurred in appearing at, participating in or defending any such proceeding in advance of its final disposition or in connection with a proceeding brought to establish or enforce a right to indemnification or advancement of expenses under the Bylaws. We believe these provisions in the Certificate of Incorporation and Bylaws are necessary to attract and retain qualified persons as directors and officers. For additional information, see “Directors, Executive Officers and Corporate Governance — Limitation of Liability and Indemnification of Directors and Officers.”

Director Independence

Nautilus and its affiliates under common control beneficially own a majority of the voting power of all outstanding shares of our common. As a result, AleAnna is a “controlled company” within the meaning of the Nasdaq Listing Rules. Under the Nasdaq Listing Rules, a company of which more than 50% of the voting power for the election of directors is held by an individual, group or another company is a “controlled company” and may elect not to comply with certain corporate governance standards, including the requirements (i) that a majority of its board of directors consist of independent directors, (ii) that its board of directors have a compensation committee that is composed entirely of independent directors with a written charter addressing the committee’s purpose and responsibilities and (iii) that director nominees must either be selected, or recommended for the board’s selection, either by independent directors constituting a majority of the board’s independent directors in a vote in which only independent directors participate, or a nominating and corporate governance committee comprised solely of independent directors with a written charter addressing the committee’s purpose and responsibilities. Notwithstanding the availability of such exemptions, a majority of AleAnna’s current Board members qualify as independent under applicable Nasdaq rules.

Nasdaq rules generally require that independent directors must comprise a majority of a listed company’s board of directors. Under the rules of Nasdaq, a director generally only qualifies as an “independent director” if the director and, in the opinion of that company’s board of directors, that person does not have a relationship that would interfere with the exercise of independent judgment in carrying out the responsibilities of a director, subject

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to certain “bright-line” determinations that would result in a director not being deemed independent for purposes of Nasdaq rules. Based upon information requested from and provided by each proposed director concerning his or her background, employment and affiliations, including family relationships, the Board has determined that Mr. van’t Hoff, Mr. Palmer and Mr. Hébert are “independent” as that term is defined under the applicable rules and regulations of the SEC and the listing requirements and rules of Nasdaq.

Indemnification Agreements

The Company entered into separate indemnification agreements with each of its directors and officers. These agreements, among other things, are expected to require the Company to indemnify its directors and officers for certain expenses, including attorneys’ fees, judgments, fines and settlement amounts incurred by a director or officer in any action or proceeding arising out of their services as one of its directors or officers or any other company or enterprise to which the person provides services at its request. We believe these indemnification agreements are necessary to attract and retain qualified persons as directors and officers.

Certain of the foregoing disclosures are summaries of certain provisions of our related party agreements, and are qualified in their entirety by reference to all of the provisions of such agreements. Because these descriptions are only summaries of the applicable agreements, they do not necessarily contain all of the information that you may find useful.

Transactions Prior to Execution of the Merger Agreement

Intercompany Payables

As of December 31, 2023, AleAnna Energy had outstanding payables of $525,276, to its parent company, Nautilus, primarily related to the payment of legal fees by Nautilus on behalf of AleAnna. These intercompany payables are presented as related party payables on the accompanying condensed consolidated balance sheets and were settled in the normal course of business. Except for capital contributions received from Nautilus during the year ended December 31, 2024, and 2023, as presented in the consolidated statements of changes in shareholders’ and members’ equity, or as otherwise disclosed, there were no other related party transactions entered into during the periods presented that required recognition or disclosure.

Capital Contributions

Nautilus made a capital contribution of $651,750 to AleAnna in April 2024 in exchange for 651 units and $17.1 million to AleAnna in May 2024 in exchange for 17,100 units.

Policies and Procedures for Related Party Transactions

On December 13, 2024 the Company adopted a new written related party transaction policy (the “Related Party Transactions Policy”) that sets forth the following policies and procedures for the review and approval or ratification of related party transactions.

A “Related Party Transaction,” as defined in the Related Party Transaction Policy, means any transaction, arrangement, or relationship, or any series of similar transactions, arrangements, or relationships, in which (i) the Company or any of its subsidiaries is or will be a participant; (ii) the aggregate amount involved will or may be expected to material interest. A “Related Party” means:

1. any person who is or was (since the beginning of the last fiscal year for which the Company has filed an Annual Report on Form 10-K and proxy statement, even if such person does not presently serve in that role) an executive officer, director, or nominee for director of the Company;

2. any shareholder that beneficially owns more than 5% of any class of the Company’s voting securities;

3. an Immediate Family Member of any such person; or

4. any firm, corporation or other entity in which any of such persons is employed or is a general partner or principal or in a similar position or in which such person has a 10% or greater beneficial ownership interest.

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Under the Company’s related party transaction policy, if a transaction has been identified as a Related Party Transaction, including any transaction that was not a Related Party Transaction when originally consummated or any transaction that was not initially identified as a Related Party Transaction prior to consummation, the Company’s management must notify the Company’s Corporate Counsel in writing of the facts and circumstances regarding the proposed Related Party Transaction to the Company’s Audit Committee.

The policy requires that, in determining whether to approve, ratify or reject a Related Party Transaction, the Audit Committee shall review all of the relevant facts and information available to it about, as well as circumstances of, all Related Party Transactions and either approve or disapprove of the entry into the Related Party Transaction, subject to the exceptions described in the Related Party Transaction Policy. The Audit Committee may approve the Related Party Transaction only if the Audit Committee determines in good faith that the transaction is not inconsistent with the interests of the Company and its shareholders.

All of the transactions described in this section were entered into prior to the adoption of this policy.

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SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT

The following table sets forth information known to the Company regarding beneficial ownership of the Company’s securities as of April 16, 2025, by:

• each person known by the Company who is the beneficial owner of more than 5% of the outstanding Class A Common Stock or Class C Common Stock;

• each of the Company’s executive officers and directors; and

• all of the Company’s executive officers and directors as a group.

As of April 16, 2025, AleAnna had 40,584,455 shares of Class A Common Stock issued and outstanding and 25,994,400 shares of Class C Common Stock issued and outstanding. Except as otherwise noted herein, the number and percentage of Class A Common Stock and Class C Common Stock beneficially owned is determined in accordance with Rule 13d-3 of the Exchange Act, and the information is not necessarily indicative of beneficial ownership for any other purpose. Under such rule, beneficial ownership includes any Class A Common Stock as to which the holder has sole or shared voting power or investment power and also any Class A Common Stock which the holder has the right to acquire within 60 days of through the exercise of any option, warrant or any other right, including shares of non-economic voting Class C Common Stock that may be exchanged, together with Class C HoldCo Units, for Class A Common Stock. Shares subject to warrants that are currently exercisable or exercisable within 60 days of the Closing Date are considered outstanding and beneficially owned by the person holding such warrants for the purpose of computing the percentage ownership of that person but are not treated as outstanding for the purpose of computing the percentage ownership of any other person.

Unless otherwise indicated and subject to community property laws and similar laws, the Company believes that all parties named in the table below have sole voting and investment power with respect to all shares of Class A Common Stock and Class C Common Stock beneficially owned by them.

Name of Beneficial Owner(1) |  | Number of Shares of Class A Common Stock |  | % of Class A Common Stock |  | Number of Shares of Class C Common Stock |  | % of Class C Common Stock |  | Combined Voting Power
5% or Greater Shareholders |  |  |  |  |  |  |  |  |  |  |  |  |
Nautilus Resources LLC(2) |  | 30,478,724 |  | 75.10 | % |  | 25,994,400 |  | 100 | % |  | 84.82 | %
John and Susan Wilder Foundation(3) |  | 6,655,470 |  | 16.40 | % |  | — |  | — |  |  | 9.99 | %
Directors and Executive Officers |  |  |  |  |  |  |  |  |  |  |  |  |
Graham van’t Hoff |  | — |  | — |  |  | — |  | — |  |  | — |
William K. Dirks |  | — |  | — |  |  | — |  | — |  |  | — |
Marco Brun |  | — |  | — |  |  | — |  | — |  |  | — |
Duncan Palmer |  | — |  | — |  |  | — |  | — |  |  | — |
Curtis Hébert |  | — |  | — |  |  | — |  | — |  |  | — |
Tristan Yopp |  | — |  | — |  |  | — |  | — |  |  | — |
Charles Roscopf |  | — |  | — |  |  | — |  | — |  |  | — |
All executive officers and directors as a group (seven persons) |  | — |  | — |  |  | — |  | — |  |  | — |

____________

(1) Unless otherwise noted, the business address of each of the following entities and individuals is c/o AleAnna, Inc., 300 Crescent Court, Suite 1860 Dallas, Texas 75201.

(2) The securities beneficially owned by Nautilus Resources LLC are indirectly beneficially owned by Charles John Wilder, Jr. and Susan Anne Wilder, as the managing members of JSW Interests LLC, which is the sole member of JSW Energy Holdings LLC, which is the general partner of JSW Energy Interests LP, which is the sole member of Bluescape Resources Investors LLC, which is the manager of Bluescape Resources Company LLC, which is the general partner of BRC Property Holdings LP, which is the manager of BRC-Oxy Marcellus Tax Partnership LLC, which is the sole member of BRC Exploration Holdings LLC, which is the sole member of Nautilus Resources LLC. Each individual and entity referenced herein disclaims the existence of a “group” and disclaims beneficial ownership of all Class C HoldCo Units, other than any Class C HoldCo Units or other securities reported herein as being owned by it, him or her, as the case may be. The address for each party referenced herein is 300 Crescent Court, Suite 1860 Dallas, Texas 75201.

(3) The John and Susan Wilder foundation is managed and controlled by Charles John Wilder, Jr., together with his spouse.

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DESCRIPTION OF SECURITIES

The following summary of certain provisions of the Company’s securities does not purport to be complete and is subject to the Certificate of Incorporation, the Bylaws and the provisions of applicable law.

Authorized and Outstanding Stock

The total amount of authorized capital stock of the Company is 223,500,000 shares, consisting of:

• 150,000,000 shares of Class A Common Stock, par value $0.0001 per share;

• 2,500,000 shares of Class B Common Stock, par value $0.0001 per share;

• 70,000,000 shares of Class C Common Stock, par value $0.0001 per share; and

• 1,000,000 shares of Preferred Stock, par value $0.0001 per share.

As of April 16, 2025, 40,584,455 shares of Class A Common Stock are outstanding, no shares of Class B Common Stock are outstanding, 25,994,400 shares of Class C Common Stock are outstanding, no shares of Preferred Stock outstanding and 11,225,969 Public Warrants are outstanding.

Class A Common Stock

There are 40,584,455 shares of Class A Common Stock outstanding.

Voting rights. Each holder of Class A Common Stock is entitled to one vote for each share of Class A Common Stock held of record by such holder on all matters on which stockholders generally are entitled to vote (whether voting separately as a class or together with one or more classes of the Company’s capital stock). Holders of shares of Class A Common Stock vote together with holders of the Class C Common Stock as a single class on all matters presented to the Company’s stockholders for their vote or approval. Generally, all matters to be voted on by stockholders must be approved by a majority (or, in the case of election of directors, by a plurality) of the votes entitled to be cast by all stockholders present in person or represented by proxy, voting together as a single class, provided that a quorum is present, and further provided that, prior to the Trigger Date, certain provisions of our Certificate of Incorporation may only be amended by a vote of two-thirds of the total votes entitled to be cast by all stockholders present in person or represented by proxy, voting together as a single class. The holders of the outstanding shares of Class A Common Stock shall be entitled to vote separately as a single class upon any amendment to this Certificate of Incorporation (including by merger, consolidation, reorganization or similar event) that would alter or change the powers, preferences, special or other rights of Class A Common Stock in a manner that is disproportionately adverse as compared to the powers, preferences, special or other rights of Class C Common Stock. Notwithstanding the foregoing, to the fullest extent permitted by law, holders of Class A Common Stock, as such, have no voting power pursuant to the Certificate of Incorporation with respect to, and are not entitled to vote on, any amendment to the Certificate of Incorporation (including any certificate of designations relating to any series of Preferred Stock) that relates solely to the terms of one or more outstanding series of Preferred Stock if the holders of such affected series of Preferred Stock are entitled to vote as a separate class thereon pursuant to the Certificate of Incorporation (including any certificate of designations relating to any series of Preferred Stock) or pursuant to the DGCL.

Dividend Rights. Subject to preferences that may be applicable to any outstanding Preferred Stock, the holders of shares of Class A Common Stock are entitled to receive ratably such dividends, if any, as may be declared from time to time by the Board out of funds legally available therefor.

Rights upon liquidation. In the event of any voluntary or involuntary liquidation, dissolution or winding up of the Company’s affairs, after payment of the Company’s debts and other liabilities, subject to prior distribution rights of Preferred Stock or any class or series of stock having a preference over the Class A Common Stock, then outstanding, if any, the holders of Class A Common Stock are entitled to receive, pari passu, an amount per share equal to the par value thereof. Thereafter the holders of all outstanding shares of Class A Common Stock are entitled to share ratably in all net assets remaining available for distribution.

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Other rights. The holders of Class A Common Stock have no preemptive or conversion rights or other subscription rights. There are no redemption or sinking fund provisions applicable to the Class A Common Stock. The rights, preferences and privileges of holders of the Class A Common Stock are subject to those of the holders of any shares of the Preferred Stock the Company may issue in the future.

Class C Common Stock

There are 25,994,400 shares of Class C Common Stock outstanding.

Voting rights. Each holder of Class C Common Stock is entitled to one vote for each share of Class C Common Stock held of record by such holder on all matters on which stockholders generally are entitled to vote (whether voting separately as a class or together with one or more classes of the Company’s capital stock). Holders of shares of Class C Common Stock vote together with holders of the Class A Common Stock as a single class on all matters presented to the Company’s stockholders for their vote or approval. Generally, all matters to be voted on by stockholders must be approved by a majority (or, in the case of election of directors, by a plurality) of the votes entitled to be cast by all stockholders present in person or represented by proxy, voting together as a single class, provided that a quorum is present, and further provided that, prior to the Trigger Date, certain provisions of our Certificate of Incorporation may only be amended by a vote of two-thirds of the total votes entitled to be cast by all stockholders present in person or represented by proxy, voting together as a single class. The holders of the outstanding shares of Class C Common Stock shall be entitled to vote separately as a single class upon any amendment to this Certificate of Incorporation (including by merger, consolidation, reorganization or similar event) that would alter or change the powers, preferences, special or other rights of Class C Common Stock in a manner that is disproportionately adverse as compared to the powers, preferences, special or other rights of Class A Common Stock. Notwithstanding the foregoing, to the fullest extent permitted by law, holders of Class C Common Stock, as such, have no voting power pursuant to the Certificate of Incorporation with respect to, and are not entitled to vote on, any amendment to the Certificate of Incorporation (including any certificate of designations relating to any series of Preferred Stock) that relates solely to the terms of one or more outstanding series of Preferred Stock if the holders of such affected series of Preferred Stock are entitled to vote as a separate class thereon pursuant to the Certificate of Incorporation (including any certificate of designations relating to any series of Preferred Stock) or pursuant to the DGCL.

Dividend rights. The holders of the Class C Common Stock do not participate in any dividends declared by the Board.

Rights upon liquidation. In the event of any voluntary or involuntary liquidation, dissolution or winding up of the Company’s affairs, the holders of Class C Common Stock are not entitled to receive any assets of the Company in excess of the par value thereof.

Other rights. The holders of shares of Class C Common Stock do not have preemptive, subscription, redemption or conversion rights. There are no redemption or sinking fund provisions applicable to the Class C Common Stock.

Exchange and Cancellation. To the extent that a holder of Class C Common Stock exchanges its Class C LLC Units with a corresponding number of shares of Class C Common Stock for shares of Class A Common Stock in accordance with the A&R HoldCo LLC Agreement, the shares of Class C Common Stock so exchanged shall automatically, and without further action on the part of the Company or any holder of Class C Common Stock, be cancelled for no consideration.

Preferred Stock

No shares of Preferred Stock are issued or outstanding. The Certificate of Incorporation authorizes the Board to establish one or more series of Preferred Stock. Unless required by law or any stock exchange, the authorized shares of Preferred Stock are available for issuance without further action by the holders of the Class A Common Stock or Class C Common Stock. The Board has the discretion to determine the powers, preferences and relative, participating, optional and other special rights, including voting rights, dividend rights, conversion rights, redemption privileges and liquidation preferences, of each series of Preferred Stock.

The issuance of Preferred Stock may have the effect of delaying, deferring or preventing a change in control of the Company without further action by the stockholders. The existence of authorized but unissued shares of preferred stock may enable our Board to discourage an attempt to obtain control of us by means of a merger, tender offer, proxy

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contest or otherwise. Additionally, the issuance of Preferred Stock may adversely affect the holders of the Class A Common Stock by restricting dividends on the Class A Common Stock, diluting the voting power of the Class A Common Stock and the Class C Common Stock or subordinating the liquidation rights of the Class A Common Stock. As a result of these or other factors, the issuance of Preferred Stock could have an adverse impact on the market price of the Class A Common Stock.

Public Warrants

There are 11,225,969 Public Warrants outstanding. Each whole Public Warrant entitles the registered holder to purchase one share of Class A Common Stock at a price of $11.50 per share, subject to adjustment as discussed below, at any time commencing on January 12, 2025, provided in each case that we have an effective registration statement under the Securities Act covering the shares of Class A Common Stock issuable upon exercise of the Public Warrants and a current prospectus relating to them is available (or we permit holders to exercise their Public Warrants on a cashless basis under the circumstances specified in the warrant agreement) and such shares are registered, qualified or exempt from registration under the securities, or blue sky, laws of the state of residence of the holder. Pursuant to the warrant agreement, a Public Warrant holder may exercise its Public Warrants only for a whole number of shares of Class A Common Stock. This means only a whole Public Warrant may be exercised at a given time by a Public Warrant holder. No fractional Public Warrants will be issued upon the separation of the units, and only whole Public Warrants will trade. The Public Warrants will expire on December 13, 2029, at 5:00 p.m., New York City time, or earlier upon redemption or liquidation.

We are obligated to deliver any shares of Class A Common Stock pursuant to the exercise of a Public Warrant and have no obligation to settle such Public Warrant exercise unless a registration statement under the Securities Act with respect to the shares of Class A Common Stock underlying the Public Warrants is then effective and a prospectus relating thereto is current, subject to our satisfying our obligations described below with respect to registration. No Public Warrant is exercisable, and we are not obligated to issue shares of Class A Common Stock upon the exercise of a Public Warrant unless the shares of Class A Common Stock issuable upon such Public Warrant exercise are registered, qualified or deemed to be exempt under the securities laws of the state of residence of the registered holder of the Public Warrants. In the event that the conditions in the two immediately preceding sentences are not satisfied with respect to a Public Warrant, the holder of such Public Warrant is not entitled to exercise such Public Warrant, and such Public Warrant may have no value and expire worthless. In no event are we required to net cash settle any Public Warrant.

We have agreed to use our commercially reasonable efforts to file with the SEC a registration statement for the registration, under the Securities Act, of the Class A Common Stock issuable upon exercise of the Public Warrants. If a registration statement covering the Class A Common Stock issuable upon exercise of the Public Warrants is not effective by February 11, 2025, Public Warrant holders may, until such time as there is an effective registration statement and during any period when we will have failed to maintain an effective registration statement, exercise Public Warrants on a “cashless basis” in accordance with Section 3(a)(9) of the Securities Act or another exemption. Notwithstanding the above, if our shares of Class A Common Stock are at the time of any exercise of a Public Warrant not listed on a national securities exchange such that they satisfy the definition of a “covered security” under Section 18(b)(1) of the Securities Act, we may, at our option, require holders of Public Warrants who exercise their Public Warrants to do so on a “cashless basis” in accordance with Section 3(a)(9) of the Securities Act and, in the event we so elect, we will not be required to file or maintain in effect a registration statement, and in the event we do not so elect, we will use our commercially reasonable efforts to register or qualify the shares under applicable blue sky laws to the extent an exemption is not available. In such event, each holder would pay the exercise price by surrendering the warrants for that number of shares of Class A Common Stock equal to the lesser of the quotient obtained by dividing (x) the product of the number of shares of Class A Common Stock underlying the Public Warrants, multiplied by the difference between the “warrant price” (defined below) and the “fair market value” (defined below) by (y) the fair market value, provided that no cashless exercise shall be permitted unless the fair market value is equal to or higher than the warrant price. The “fair market value” as used in this paragraph shall mean the average reported last sale price of the Class A Common Stock for the 10 trading days ending on the third trading day prior to the date on which the notice of exercise of the Public Warrant is received by the warrant agent. The “warrant price” as used in this paragraph shall mean the price per share at which the Class A Common Stock may be purchased at the time a Public Warrant is exercised.

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Redemption of Public Warrants when the last sales price of our Class A Common Stock equals or exceeds $18.00.

We may call the Public Warrants for redemption:

• in whole and not in part;

• at a price of $0.01 per Public Warrant;

• upon not less than 30 days’ prior written notice of redemption (the “30-day redemption period”) to each Public Warrant holder;

• if, and only if, the reported last sale price of the Class A Common Stock equals or exceeds $18.00 per share (as adjusted for share splits, share capitalizations, reorganizations, recapitalizations and the like) on each of 20 trading days within a 30-trading day period ending on the third trading day before we send to the notice of redemption to the Public Warrant holders; and

• if, and only if, there is a current registration statement in effect with respect to the Class A Common Stock underlying such Public Warrants.

We will not redeem the Public Warrants as described above unless a registration statement under the Securities Act covering the issuance of the Class A Common Stock issuable upon exercise of the Public Warrants is then effective and a current prospectus relating to those shares of Class A Common Stock is available throughout the 30-day redemption period. In the event that we elect to redeem all of the redeemable Public Warrants, we will fix a date for the redemption. Pursuant to the terms of the warrant agreement, notice of redemption will be mailed by first class mail, postage prepaid, by not less than 30 days prior to the redemption date to the registered holders of the redeemable Public Warrants to be redeemed at their last addresses as they appear on the registration books. Any notice mailed in the manner provided in the warrant agreement will be conclusively presumed to have been duly given whether or not the registered holder received such notice.

We have established the last of the redemption criterion discussed above to prevent a redemption call unless there is at the time of the call a significant premium to the Public Warrant exercise price. If the foregoing conditions are satisfied and we issue a notice of redemption of the Public Warrants, each Public Warrant holder will be entitled to exercise his, her or its Public Warrant prior to the scheduled redemption date. However, the price of the Class A Common Stock may fall below the $18.00 redemption trigger price (as adjusted for share splits, share capitalizations, reorganizations, recapitalizations and the like) as well as the $11.50 Public Warrant exercise price after the redemption notice is issued.

Redemption Procedures and Cashless Exercise

If we call the Public Warrants for redemption as described above, our management will have the option to require any holder that wishes to exercise his, her or its Public Warrant to do so on a “cashless basis.” In determining whether to require all holders to exercise their Public Warrants on a “cashless basis,” our management will consider, among other factors, our cash position, the number of Public Warrants that are outstanding and the dilutive effect on our shareholders of issuing the maximum number of Class A Common Stock issuable upon the exercise of our Public Warrants. If our management takes advantage of this option, all holders of Public Warrants would pay the exercise price by surrendering their Public Warrants for that product of the number of Class A Common Stock underlying the Public Warrants equal to the quotient obtained by dividing (x) the product of the number of shares of Class A Common Stock underlying the Public Warrants, multiplied by the difference between the “warrant price” (defined below) and the “fair market value” (defined below) by (y) the “fair market value”. The “fair market value” will mean the average reported last sale price of the Class A Common Stock for the 10 trading days ending on the third trading day prior to the date on which the notice of redemption is sent to the holders of Public Warrants. The “warrant price” as used in this paragraph shall mean the price per share at which the Class A Common Stock may be purchased at the time a Public Warrant is exercised. If our management takes advantage of this option, the notice of redemption will contain the information necessary to calculate the number of Class A Common Stock to be received upon exercise of the Public Warrants, including the “fair market value” in such case. Requiring a cashless exercise in this manner will reduce the number of shares to be issued and thereby lessen the dilutive effect of a warrant redemption. We believe this feature is an attractive option to us if we do not need the cash from the exercise of the Public Warrants.

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Anti-dilution Adjustments

If the number of shares of outstanding Class A Common Stock is increased by a share capitalization payable in shares of Class A Common Stock, or by a stock dividend, split-up of shares of Class A Common Stock or other similar event, then, on the effective date of such stock dividend, split-up or similar event, the number of shares of Class A Common Stock issuable on exercise of each Public Warrant will be increased in proportion to such increase in the outstanding Class A Common Stock.

In addition, if we, at any time while the Public Warrants are outstanding and unexpired, pay a dividend or make a distribution in cash, securities or other assets to the holders of Class A Common Stock on account of such Class A Common Stock (or other securities into which the Public Warrants are convertible), other than (i) as described above or (ii) certain ordinary cash dividends.

If the number of outstanding shares of Class A Common Stock is decreased by a consolidation, combination, reverse share split or reclassification of Class A Common Stock or other similar event, then, on the effective date of such consolidation, combination, reverse share split, reclassification or similar event, the number of shares of Class A Common Stock issuable on exercise of each Public Warrant will be decreased in proportion to such decrease in outstanding Class A Common Stock.

Whenever the number of shares of Class A Common Stock purchasable upon the exercise of the Public Warrants is adjusted, as described above, the Public Warrant exercise price will be adjusted by multiplying the Public Warrant exercise price immediately prior to such adjustment by a fraction (x) the numerator of which will be the number of shares of Class A Common Stock purchasable upon the exercise of the Public Warrants immediately prior to such adjustment and (y) the denominator of which will be the number of shares of Class A Common Stock so purchasable immediately thereafter.

In case of any reclassification or reorganization of the outstanding shares of Class A Common Stock (other than those described above or that solely affects the par value of such shares of Class A Common Stock), or in the case of any merger or consolidation of us with or into another corporation (other than a consolidation or merger in which we are the continuing corporation and that does not result in any reclassification or reorganization of our outstanding Class A Common Stock), or in the case of any sale or conveyance to another corporation or entity of the assets or other property of us as an entirety or substantially as an entirety in connection with which we are dissolved, the holders of the Public Warrants will thereafter have the right to purchase and receive, upon the basis and upon the terms and conditions specified in the Public Warrants and in lieu of the shares of Class A Common Stock immediately theretofore purchasable and receivable upon the exercise of the rights represented thereby, the kind and amount of stock or other securities or property (including cash) receivable upon such reclassification, reorganization, merger or consolidation, or upon a dissolution following any such sale or transfer, that the holder of the Public Warrants would have received if such holder had exercised their Public Warrants immediately prior to such event.

The Public Warrants were issued in registered form under a warrant agreement between Continental Stock Transfer & Trust Company, as warrant agent, and us. The warrant agreement provides that the terms of the Public Warrants may be amended without the consent of any holder to cure any ambiguity or correct any defective provision.

The Public Warrants may be exercised upon surrender of the warrant certificate on or prior to the expiration date at the offices of the warrant agent or at the office of its successor as Public Warrant Agent, in the Borough of Manhattan, City and State of New York, with the subscription form, duly executed as indicated, accompanied by full payment of the warrant price for each full share of Class A Common Stock as to which the Public Warrant is exercised and any and all applicable taxes due in connection with the exercise of the Public Warrant. The Public Warrant holders do not have the rights or privileges of holders of Class A Common Stock and any voting rights until they exercise their Public Warrants and receive shares of Class A Common Stock. After the issuance of shares of Class A Common Stock upon exercise of the Public Warrants, each holder will be entitled to one vote for each share held of record on all matters to be voted on by shareholders.

No fractional shares of Class A Common Stock will be issued upon exercise of the Public Warrants. If, upon exercise of the Public Warrants, a holder would be entitled to receive a fractional interest in a share, we will, upon exercise, round down to the nearest whole number the number of shares of Class A Common Stock to be issued to the Public Warrant holder.

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We have agreed that, subject to applicable law, any action, proceeding or claim against us arising out of or relating in any way to the warrant agreement, including under the Securities Act, will be brought and enforced in the courts of the State of New York or the United States District Court for the Southern District of New York, and we irrevocably submit to such jurisdiction, which jurisdiction will be the exclusive forum for any such action, proceeding or claim. See “Risk Factors — The exclusive forum clause set forth in the warrant agreement governing the Public Warrants may have the effect of limiting an investor’s rights to bring legal action against us and could limit the investor’s ability to obtain a favorable judicial forum for disputes with us.”

Dividends

We have not declared any dividends, and the Board will consider whether or not to institute a divided policy in the future. The payment of future dividends on the shares of Class A Common Stock will depend on the financial condition of the Company after the completion of the Business Combination subject to the discretion of the Board.

The Company is a holding company with no material assets other than its interest in HoldCo.

Anti-Takeover Effects of the Certificate of Incorporation, the Bylaws and Certain Provisions of Delaware Law

The Certificate of Incorporation, the Bylaws and the DGCL contain provisions, which are summarized in the following paragraphs, which are intended to enhance the likelihood of continuity and stability in the composition of the Board and to discourage certain types of transactions that may involve an actual or threatened acquisition of the Company. These provisions are intended to avoid costly takeover battles, reduce the Company’s vulnerability to a hostile change of control or other unsolicited acquisition proposal, and enhance the ability of the Board to maximize stockholder value in connection with any unsolicited offer to acquire the Company. However, these provisions may have the effect of delaying, deterring or preventing a merger or acquisition of the Company by means of a tender offer, a proxy contest or other takeover attempt that a stockholder might consider in its best interest, including attempts that might result in a premium over the prevailing market price for the shares of Class A Common Stock.

Authorized but Unissued Capital Stock

Delaware law does not require stockholder approval for any issuance of authorized shares. However, the listing requirements of Nasdaq, which would apply if and so long as the Class A Common Stock remains listed on Nasdaq, require stockholder approval of certain issuances equal to or exceeding 20% of the then outstanding voting power or then outstanding number of shares of Class A Common Stock. Additional shares that may be issued in the future may be used for a variety of corporate purposes, including future public offerings, to raise additional capital or to facilitate acquisitions.

The Company will at all times reserve and keep available out of its authorized and unissued shares of Class A Common Stock, solely for the purpose of the issuance in connection with the exchange of Class C HoldCo Units and a corresponding number of shares of Class C Common Stock pursuant to the A&R HoldCo LLC Agreement, the number of shares of Class A Common Stock that are issuable upon exchange of all outstanding Class C HoldCo Units and all outstanding shares of Class C Common Stock pursuant to the A&R HoldCo LLC Agreement.

One of the effects of the existence of unissued and unreserved common stock may be to enable the Board to issue shares to persons friendly to current management, which issuance could render more difficult or discourage an attempt to obtain control of the Company by means of a merger, tender offer, proxy contest or otherwise and thereby protect the continuity of management and possibly deprive stockholders of opportunities to sell their shares of Class A Common Stock at prices higher than prevailing market prices.

Election of Directors and Vacancies

The Certificate of Incorporation provides that the number of directors of the Company shall be five and thereafter, the Board will determine the number of directors who will serve on the Board. The Board is divided into three classes designated as Class I, Class II and Class III. Class I directors serve for a term expiring at the first annual meeting of stockholders following the Closing Date. Class II and Class III directors serve for a term expiring at the second and third annual meeting of stockholders following the Closing Date, respectively. Classes I and II consists of two directors each, and Class III consists of one director. At each succeeding annual meeting of stockholders, directors will be elected for a full term of three years to succeed the directors of the class whose terms expire at such annual

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meeting of the stockholders. There is no limit on the number of terms a director may serve on the Board. In addition, the Certificate of Incorporation provides that any vacancy on the Board, including a vacancy that results from an increase in the number of directors or a vacancy that results from the removal of a director with cause, may be filled only by a majority of the directors then in office.

Notwithstanding the foregoing provisions of this section, each director will serve until his successor is duly elected and qualified or until his earlier death, resignation, retirement, disqualification or removal. No decrease in the number of directors constituting the Board will shorten the term of any incumbent director.

Corporate Opportunities

The Certificate of Incorporation sets forth provisions to regulate and define the conduct of certain of our affairs with respect to certain classes or categories of business opportunities as they may involve any of Bluescape, the non-employee directors or their respective affiliates and the powers, rights, duties and liabilities of us and our Directors, officers and stockholders in connection therewith.

Written Consent by Stockholders

Under the Certificate of incorporation, subject to the rights of holders of Preferred Stock, any action required or permitted to be taken by our stockholders may be effected (i) at a duly called annual or special meeting of our stockholders or (ii) until such time that we are no longer a “Controlled Company” pursuant to Nasdaq Listing Rule 5615(c)(1) (the “Trigger Event”), by the consent in writing of the holders of a majority of the total voting power of our outstanding shares of capital stock entitled to vote generally in the election of directors, voting together as a single class, in lieu of a duly called annual or special meeting of stockholders.

Special Meeting of Stockholders

The Certificate of Incorporation will, subject to any special rights of the holders of any series of Preferred Stock, and to the requirements of applicable law, special meetings of our stockholders may be called only by the chairperson of the Board, our chief executive officer, at the direction of our Board pursuant to a written resolution adopted by a majority of the total number of directors that we would have if there were no vacancies, or, until the Trigger Event, pursuant to a written resolution adopted by holders of a majority of the total voting power of the outstanding shares of our capital stock entitled to vote generally in the election of directors, voting together as a single class. Any business transacted at any special meeting of stockholders shall be limited to matters relating to the purpose or purposes stated in the notice of meeting.

Business Combinations

The Company has elected not to be governed by Section 203 of the DGCL.

Quorum

The Bylaws provide that at any meeting of the Board a majority of the total number of directors then authorized constitutes a quorum for all purposes. The Bylaws provide that majority of the voting power of the stock outstanding and entitled to vote at the meeting of stockholders, present in person or represented by proxy, shall constitute a quorum for the transaction of business; provided, however, that where a separate vote by a class or series or classes or series is required, a majority of the voting power of the stock of such class or series or classes or series outstanding and entitled to vote on that matter, present in person or represented by proxy, shall constitute a quorum entitled to take action with respect to such matter.

No Cumulative Voting

Under Delaware law, the right to vote cumulatively does not exist unless the Certificate of Incorporation expressly authorizes cumulative voting. The Certificate of Incorporation does not authorize cumulative voting.

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Requirements for Advance Notification of Stockholder Meetings, Nominations and Proposals

The Bylaws establish advance notice procedures with respect to stockholder proposals and the nomination of candidates for election as directors, other than nominations made by or at the direction of the Company’s Board or its committees. For any matter to be “properly brought” before a meeting, a stockholder will have to comply with advance notice requirements and provide the Company with certain information. Generally, to be timely, a stockholder’s notice must be received at the Company’s principal executive offices not less than 90 days nor more than 120 days prior to the first anniversary date of the immediately preceding annual meeting of stockholders. The Bylaws also specify requirements as to the form and content of a stockholder’s notice. The Bylaws allow the presiding officer at a meeting of the stockholders to adopt rules and regulations for the conduct of meetings which may have the effect of precluding the conduct of certain business at a meeting if the rules and regulations are not followed. These provisions may also defer, delay or discourage a potential acquirer from conducting a solicitation of proxies to elect the acquirer’s own slate of directors or otherwise attempting to influence or obtain control of the Company.

Approval Provisions

The Certificate of Incorporation and the Bylaws provide that the Board is expressly authorized to adopt, amend or repeal, in whole or in part, the Bylaws without a stockholder vote in any matter not inconsistent with the laws of the State of Delaware or the Certificate of Incorporation. Any amendment, alteration, rescission or repeal of the Bylaws by the Company’s stockholders requires the affirmative vote of the holders of at least a majority of the voting power of all the then outstanding shares of the Company’s stock entitled to vote thereon, voting together as a single class.

Prior to the Trigger Date, the Certificate of Incorporation provides that members of the Board may be removed for cause by at least two-thirds of the voting power of all of the then outstanding shares of voting stock of the Company entitled to vote at an election of directors.

The DGCL provides generally that the affirmative vote of a majority of the outstanding shares entitled to vote thereon, voting together as a single class, is required to amend a corporation’s Certificate of Incorporation, unless the Certificate of Incorporation requires a greater percentage. The Certificate of Incorporation provides that Section 5.2, Section 5.3, Section 6.1, Section 6.2. Article VII, Section 8.2, Article IX and Article XI therein, including the following provisions therein may be altered, amended or repealed only by the affirmative vote of the holders of at least two-thirds in voting power of all the then outstanding shares of the Company’s stock entitled to vote thereon, voting together as a single class:

• the provisions regarding filling vacancies on the Board and newly created directorships;

• the provisions regarding resignation and removal of directors;

• the provisions regarding stockholder action by written consent;

• the provisions regarding meetings of stockholders;

• the provisions regarding personal liability of directors and officers and the right to indemnification;

• the provision regarding amending the Bylaws;

• the exclusive forum provisions; and

• the provisions regarding corporate opportunities.

These provisions may have the effect of deterring hostile takeovers or delaying or preventing changes in control of the Company or its management, such as a merger, reorganization or tender offer. These provisions are intended to enhance the likelihood of continued stability in the composition of the Board and its policies and to discourage certain types of transactions that may involve an actual or threatened acquisition of the Company. These provisions are designed to reduce the Company’s vulnerability to an unsolicited acquisition proposal. The provisions are also intended to discourage certain tactics that may be used in proxy fights. However, such provisions could have the effect of discouraging others from making tender offers for the Company’s shares and, as a consequence, may inhibit fluctuations in the market price of the Company’s shares that could result from actual or rumored takeover attempts. Such provisions may also have the effect of preventing changes in management.

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Exclusive Forum

The Certificate of Incorporation provides that, unless the Company consents in writing to the selection of an alternative forum, (a) the Court of Chancery of the State of Delaware shall, to the fullest extent permitted by applicable law, be the sole and exclusive forum for (i) any derivative action or proceeding brought on behalf of the Company, (ii) any action asserting a claim of breach of a fiduciary duty owed by, or other wrongdoing by, any current or former director, officer, employee or agent of the Company to the Company or the Company’s stockholders, or a claim of aiding and abetting any such breach of fiduciary duty, (iii) any action asserting a claim against the Company or any current or former director, officer, other employee or agent of the Company arising pursuant to any provision of the DGCL, the Certificate of Incorporation (as it may be amended or restated) or the Bylaws, (iv) any action to interpret, apply, enforce or determine the validity of the Certificate of Incorporation or Bylaws, or (v) any action asserting a claim against the Company or any current or former director, officer, employee or agent of the Company governed by the internal affairs doctrine or (vi) any action asserting an “internal corporate claim” as that term is defined in Section 115 of the DGCL, and (b) the federal district courts of the United States of America shall, to the fullest extent permitted by applicable law, be the sole and exclusive forum for the resolution of any complaint asserting a cause of action arising under the Securities Act and the rules and regulations promulgated thereunder. Notwithstanding the foregoing, these exclusive forum provisions shall not apply to claims seeking to enforce any liability or duty created by the Exchange Act or any other claim for which the U.S. federal courts have exclusive jurisdiction. Any person purchasing or otherwise acquiring any interest in any shares of the Company’s capital stock shall be deemed to have notice of and to have consented to the forum provisions in the Bylaws. If any action the subject matter of which is within the scope of the forum provisions is filed in a court other than a court located within the State of Delaware (a “foreign action”) in the name of any stockholder, such stockholder shall be deemed to have consented to: (a) the personal jurisdiction of the state and federal courts located within the State of Delaware in connection with any action brought in any such court to enforce the forum provisions (an “enforcement action”); and (b) having service of process made upon such stockholder in any such enforcement action by service upon such stockholder’s counsel in the foreign action as agent for such stockholder. However, it is possible that a court could find the Company’s forum selection provisions to be inapplicable or unenforceable. Although the Company believes this provision benefits it by providing increased consistency in the application of Delaware law in the types of lawsuits to which it applies, the provision may have the effect of discouraging lawsuits against the Company’s directors, officers and other employees.

Limitations on Liability and Indemnification of Officers and Directors

The DGCL authorizes corporations to limit or eliminate the personal liability of directors to corporations and their stockholders for monetary damages for breaches of directors’ fiduciary duties, subject to certain exceptions. The Certificate of Incorporation will include a provision that eliminates, to the fullest extent permitted by law, the personal liability of directors for monetary damages for any breach of fiduciary duty as a director. The effect of these provisions is to eliminate the rights of a company and its stockholders, through stockholders’ derivative suits on a company’s behalf, to recover monetary damages from a director for breach of fiduciary duty as a director, including breaches resulting from grossly negligent behavior. However, exculpation does not apply to any director if the director has acted in bad faith, knowingly or intentionally violated the law, authorized illegal dividends or redemptions or derived an improper benefit from his or her actions as a director.

The Certificate of Incorporation provides that the Company must indemnify and advance expenses to directors and officers to the fullest extent permitted by Delaware law. The Company is also expressly authorized to carry directors’ and officers’ liability insurance providing indemnification for directors, officers and certain employees for some liabilities. The Company believes that these indemnification and advancement provisions and insurance are useful to attract and retain qualified directors and executive officers.

The limitation of liability, indemnification and advancement provisions in the Certificate of Incorporation may discourage stockholders from bringing a lawsuit against directors for breach of their fiduciary duty. These provisions also may have the effect of reducing the likelihood of derivative litigation against directors and officers, even though such an action, if successful, might otherwise benefit the Company and its stockholders. In addition, your investment may be adversely affected to the extent the Company pays the costs of settlement and damage awards against directors and officers pursuant to these indemnification provisions. The Company believes that these provisions, liability insurance and the indemnity agreements are necessary to attract and retain talented and experienced directors and officers.

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Insofar as indemnification for liabilities arising under the Securities Act may be permitted to the Company’s directors, officers and controlling persons pursuant to the foregoing provisions, or otherwise, the Company has been advised that in the opinion of the SEC such indemnification is against public policy as expressed in the Securities Act and is, therefore, unenforceable.

A&R Registration Rights Agreement

On the Closing Date, the Registration Rights Agreement was amended and restated by the Registration Rights Holders. Pursuant to the A&R Registration Rights Agreement, by February 11, 2025, the Company shall use its commercially reasonable efforts to file with the SEC (at the Company’s sole cost and expense) a registration statement registering the resale of certain securities held by or issuable to the Registration Rights Holders (the “Resale Registration Statement”), and the Company will use its commercially reasonable efforts to have the Resale Registration Statement declared effective as soon as reasonably practicable after the filing thereof. In certain circumstances, the Registration Rights Holders can demand the Company’s assistance with underwritten offerings and block trades, and the Registration Rights Holders are entitled to certain piggyback registration rights. The A&R Registration Rights Agreement does not provide for the payment of any cash penalties by the Company if it fails to satisfy any of its obligations under the A&R Registration Rights Agreement.

Transfer Agent and Warrant Agent

The transfer agent for Common Stock is Continental Stock Transfer & Trust Company.

Listing

Our shares of Class A Common Stock and Public Warrants are listed on The Nasdaq Stock Market LLC under the symbols “ANNA” and “ANNAW,” respectively.

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SECURITIES ACT RESTRICTIONS ON RESALE OF SECURITIES

Shares Eligible for Future Sale

Future sales of our Class A Common Stock in the public market, or the availability of such shares for sale in the public market, could adversely affect market prices of our Class A Common Stock prevailing from time to time. Sales of our Class A Common Stock in the public market, or the perception that those sales may occur, could adversely affect the prevailing market price at such time and our ability to raise equity capital in the future. The registration statement of which this prospectus forms a part registers up to 11,225,969 shares of Class A Common Stock constituting approximately 14.5% of our total outstanding Class A Common Stock on a fully diluted basis (assuming the issuance of all shares of Class A Common Stock issuable upon exercise of the Public Warrants and upon exchange of all outstanding Class C HoldCo Units and Class C Common Stock).

Rule 144

Pursuant to Rule 144, a person who has beneficially owned restricted shares of our Class A Common Stock or Public Warrants for at least six months would be entitled to sell their securities provided that (i) such person is not deemed to have been one of our affiliates at the time of, or at any time during the three months preceding, a sale and (ii) we are subject to the Exchange Act periodic reporting requirements for at least three months before the sale and have filed all required reports under Section 13 or 15(d) of the Exchange Act during the 12 months (or such shorter period as we were required to file reports) preceding the sale.

Persons who have beneficially owned restricted shares of our Class A Common Stock or Public Warrants for at least six months but who are our affiliates at the time of, or at any time during the three months preceding, a sale, would be subject to additional restrictions, by which such person would be entitled to sell within any three-month period only a number of securities that does not exceed the greater of:

• 1% of the total number of shares of such securities then-outstanding; or

• the average weekly reported trading volume of such securities during the four calendar weeks preceding the filing of a notice on Form 144 with respect to the sale.

• Sales by our affiliates under Rule 144 are also limited by manner of sale provisions and notice requirements and to the availability of current public information about us.

Restrictions on the Use of Rule 144 by Shell Companies or Former Shell Companies

Rule 144 is not available for the resale of securities initially issued by shell companies (other than business combination related shell companies) or issuers that have been at any time previously a shell company. However, Rule 144 also includes an important exception to this prohibition if the following conditions are met:

• the issuer of the securities that was formerly a shell company has ceased to be a shell company;

• the issuer of the securities is subject to the reporting requirements of Section 13 or 15(d) of the Exchange Act;

• the issuer of the securities has filed all Exchange Act reports and materials required to be filed, as applicable, during the preceding 12 months (or such shorter period that the issuer was required to file such reports and materials), other than Current Reports on Form 8-K; and

• at least one year has elapsed from the time that the issuer filed current Form 10 type information with the SEC reflecting its status as an entity that is not a shell company.

While we were formed as a shell company, since the completion of the Business Combination, we are no longer a shell company, and so, once the conditions set forth in the exceptions listed above are satisfied, Rule 144 will become available for the resale of the above noted restricted securities.

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Lock-up Restrictions

Concurrently with the execution of the Merger Agreement, Swiftmerge, AleAnna Energy and the Sponsor Related Parties entered into the A&R Sponsor Letter Agreement pursuant to which each Sponsor Related Party agreed to, until December 13, 2025, a customary restriction on the sale or transfer of such Sponsor Related Party’s shares of Class A Common Stock. Notwithstanding the lock-up provisions of the A&R Sponsor Letter Agreement, the Sponsor Related Parties may transfer shares of Class A Common Stock to (i) any of Swiftmerge’s officers or directors, any affiliate or family member of any of Swiftmerge’s officers or directors or any members of the Sponsor or any affiliates of the Sponsor; (ii) in the case of an individual, by gift to a member of such individual’s immediate family or to a trust, the beneficiary of which is a member of such individual’s immediate family, an affiliate of such individual or to a charitable organization; (iii) in the case of an individual, by virtue of laws of descent and distribution upon death of such individual; (iv) in the case of an individual, pursuant to a qualified domestic relations order; (v) by virtue of the laws of the State of Delaware or the Sponsor’s limited liability company agreement upon dissolution of the Sponsor; or (vi) in the event of Swiftmerge’s liquidation, merger, capital stock exchange, reorganization or other similar transaction which results in all of Swiftmerge’s shareholders having the right to exchange their shares of Swiftmerge Ordinary Shares or Closing Shares (as defined therein) for cash, securities or other property subsequent to Swiftmerge’s completion of the Transactions. Additionally, the lock-up provisions of the A&R Sponsor Letter Agreement may be waived with the consent of Swiftmerge and AleAnna.

Additionally, concurrently with the execution of the Merger Agreement, Swiftmerge and Sponsor entered into the Investor Letter Agreements, pursuant to which each investor party thereto agreed to, among other things, be bound by a customary restriction on the sale or transfer of such investor’s shares of Class A Common Stock on the same terms and conditions provided for in the Sponsor Letter Agreement.

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PLAN OF DISTRIBUTION

This prospectus relates to the issuance by us of up to 11,225,969 shares of Class A Common Stock issuable upon the exercise of an aggregate of 11,225,969 Public Warrants, each of which is exercisable at a price of $11.50 per share.

We will receive up to an aggregate of approximately $129.1 million assuming the exercise in full of all of the Public Warrants for cash. As of April 16, 2025, we have received an aggregate of approximately $276,356.50 in cash proceeds upon exercise of Public Warrants. The likelihood that holders of Public Warrants will exercise their Public Warrants and any cash proceeds that we would receive is dependent upon the market price of our Class A Common Stock. If the market price for our Class A Common Stock is less than $11.50 per share, we believe holders of our Public Warrants will be unlikely to exercise their Public Warrants. We will not pay any brokers’ or underwriters’ discounts and commissions in connection with the registration and sale of the Class A Common Stock covered by this prospectus.

We intend to keep the registration statement of which this prospectus forms a part effective until the earlier of the issuance of all shares of Class A Common Stock pursuant to this prospectus and the expiration of the Public Warrants.

We will bear all costs, fees and expenses incurred in effecting the registration of such securities covered by this prospectus, including, without limitation, all registration and filing fees, Nasdaq listing fees, and fees of our counsel and our independent registered public accountants.

Our Class A Common Stock and Public Warrants are currently listed on the Nasdaq under the symbols “ANNA” and “ANNAW”.

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LEGAL MATTERS

The validity of the securities offered hereby will be passed upon for us by Haynes and Boone, LLP, Dallas, Texas.

CHANGE IN ACCOUNTANTS

On December 13, 2024 the Audit Committee approved the dismissal of Marcum LLP (“Marcum”) as our independent registered public accounting firm, effective December 13, 2024 (the “Auditor Change Effective Date”). Marcum’s report on Swiftmerge’s financial statements as of December 31, 2023 and as of December 31, 2022 and the related statements of operations, changes in stockholders’ deficit and cash flows for the years ended December 31, 2023 and 2022 did not contain any adverse opinion or disclaimer of opinion, nor were they qualified or modified as to uncertainty, audit scope or accounting principles, other than included an explanatory paragraph as to Swiftmerge’s ability to continue as a going concern.

During the years ended December 31, 2023 and 2022 and the subsequent period through December 13, 2024, there were no “disagreements” (as that term is described in Item 304(a)(1)(iv) of Regulation S-K under the Exchange Act, and the related instructions to Item 304 of Regulation S-K under the Exchange Act) with Marcum on any matter of accounting principles or practices, financial statement disclosures or audited scope or procedures, which disagreements if not resolved to Marcum’s satisfaction would have caused Marcum to make reference to the subject matter of the disagreement in connection with its report. During the years ended December 31, 2023 and 2022 and the subsequent period through December 13, 2024, there have been no “reportable events” (as defined in Item 304(a)(1)(v) of Regulation S-K under the Exchange Act), other than the material weakness in internal controls identified by management related to the lack of ability to account for complex financial instruments. In addition, as part of such process, Swiftmerge identified a material weakness in internal control related to Swiftmerge’s review controls over the recording of an unbilled amount due to a third-party service provider and interest income, which affected the year ended December 31, 2023.

The Company has provided Marcum with a copy of the foregoing disclosures and requested that Marcum furnish us with a letter addressed to the SEC stating whether it agrees with the above statements and, if not, stating the respects in which it does not agree.

On December 13, 2024, the Board approved the engagement of Deloitte & Touche LLP (“Deloitte”) as its independent registered public accounting firm, effective upon the Auditor Change Effective Date. Deloitte previously served as the independent registered public accounting firm of AleAnna Energy prior to the Business Combination. During the years ended December 31, 2023 and 2022 and the subsequent period through December 13, 2024, neither the Company, nor anyone on the Company’s behalf consulted with Deloitte, on behalf of the Company, regarding the application of accounting principles to a specified transaction (either completed or proposed), the type of audit opinion that might be rendered on the Company’s financial statements, or any matter that was either the subject of a “disagreement,” as defined in Item 304(a)(1)(iv) of Regulation S-K, or a “reportable event,” as defined in Item 304(a)(1)(v) of Regulation S-K.

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EXPERTS

The financial statements of AleAnna, Inc. and its subsidiaries as of December 31, 2024 and 2023, and for each of the two years in the period ended December 31, 2024, included in this prospectus, have been audited by Deloitte & Touche LLP, an independent registered public accounting firm, as stated in their report. Such financial statements are included in reliance upon the report of such firm given their authority as experts in accounting and auditing.

Approximately 100% of the estimates of AleAnna’s reserves and related future net cash flows related to its properties as of December 31, 2024, included herein and elsewhere in the registration statement were based upon a reserve report prepared by independent petroleum engineers, DeGolyer and MacNaughton. We have included these estimates in reliance on the authority of such firm as an expert in such matters.

WHERE YOU CAN FIND ADDITIONAL INFORMATION

We have filed with the SEC a Registration Statement on Form S-1 under the Securities Act with respect to the securities offered hereby. This prospectus, which constitutes part of the Registration Statement, does not contain all of the information set forth in the Registration Statement and the exhibits and schedules thereto. For further information with respect to the Company and its securities, reference is made to the Registration Statement and the exhibits and any schedules filed therewith. Statements contained in this prospectus as to the contents of any contract or any other document referred to are not necessarily complete, and in each instance, we refer you to the copy of the contract or other document filed as an exhibit to this Registration Statement. Each of these statements is qualified in all respects by this reference.

You can read our SEC filings, including the Registration Statement, over the internet at the SEC’s website at www.sec.gov. We are subject to the information reporting requirements of the Exchange Act, and we are required to file reports, proxy statements and other information with the SEC. These reports, proxy statements, and other information are available for inspection and copying at the SEC’s website referred to above. We also maintain a website at www.aleannainc.com, at which you may access these materials free of charge as soon as reasonably practicable after they are electronically filed with, or furnished to, the SEC. Information contained on or accessible through our website is not a part of this prospectus, and the inclusion of our website address in this prospectus is an inactive textual reference only.

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INDEX TO FINANCIAL STATEMENTS
ALEANNA, INC.

AUDITED FINANCIAL STATEMENTS

|  | Page
Report of Independent Registered Public Accounting Firm (PCAOB ID: 34) |  | F-2
Consolidated Balance Sheets |  | F-3
Consolidated Statements of Operations and Comprehensive Loss |  | F-4
Statements of Consolidated Changes in Stockholders’ and Members’ Equity |  | F-5
Consolidated Statements of Cash Flows |  | F-7
Notes to the Consolidated Financial Statements |  | F-8

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the stockholders and the Board of Directors of AleAnna, Inc.

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of AleAnna, Inc. and subsidiaries (the “Company”) as of December 31, 2024 and 2023, the related consolidated statements of operations and comprehensive loss, changes in stockholders’ equity, and cash flows, for each of the two years in the period ended December 31, 2024, and the related notes (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2024 and 2023, and the results of its operations and its cash flows for each of the two years in the period ended December 31, 2024, in conformity with accounting principles generally accepted in the United States of America.

Basis for Opinion

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

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.

Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

/s/ Deloitte & Touche LLP

Dallas, Texas
March 31, 2025

We have served as the Company’s auditor since 2023.

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ALEANNA, INC.
CONSOLIDATED BALANCE SHEETS
AS OF DECMBER 31, 2024 AND 2023

|  | December 31, 2024 |  | December 31, 2023
ASSETS |  |  |  |  |  |  |  |
Current Assets: |  |  |  |  |  |  |  |
Cash and cash equivalents |  | $ | 28,330,159 |  |  | $ | 6,759,265 |
Accounts receivable |  |  | 1,225,297 |  |  |  | — |
Prepaid expenses and other assets |  |  | 1,666,155 |  |  |  | 27,485 |
Total Current Assets |  |  | 31,221,611 |  |  |  | 6,786,750 |
Non-current assets: |  |  |  |  |  |  |  |
Natural gas and other properties, successful efforts method |  |  | 33,979,014 |  |  |  | 22,480,830 |
Renewable natural gas properties, net of accumulated depreciation of $132,094 |  |  | 9,296,039 |  |  |  | — |
Value-added tax refund receivable |  |  | 6,845,030 |  |  |  | 4,425,353 |
Operating lease right-of-use assets |  |  | 1,744,897 |  |  |  | — |
Total Non-current Assets |  |  | 51,864,980 |  |  |  | 26,906,183 |
Total Assets |  | $ | 83,086,591 |  |  | $ | 33,692,933 |
LIABILITIES AND EQUITY |  |  |  |  |  |  |  |
Current Liabilities: |  |  |  |  |  |  |  |
Accounts payable and accrued expenses |  | $ | 2,204,208 |  |  | $ | 1,053,819 |
Related party payables |  |  | — |  |  |  | 525,276 |
Lease liability, short-term |  |  | 163,865 |  |  |  | — |
Derivative liability, at fair value |  |  | — |  |  |  | 173,177 |
Total Current Liabilities |  |  | 2,368,073 |  |  |  | 1,752,272 |
Non-current Liabilities: |  |  |  |  |  |  |  |
Asset retirement obligation |  |  | 4,375,919 |  |  |  | 4,242,680 |
Lease liability, long-term |  |  | 1,579,443 |  |  |  | — |
Contingent consideration liability, long-term |  |  | 24,994,315 |  |  |  | 26,482,682 |
Total Non-current Liabilities |  |  | 30,949,677 |  |  |  | 30,725,362 |
Total Liabilities |  |  | 33,317,750 |  |  |  | 32,477,634 |
Commitments and Contingencies (Note 6) |  |  |  |  |  |  |  |
Temporary Equity: |  |  |  |  |  |  |  |
Class 1 Preferred Units, no par value, 43,611 units authorized, issued and outstanding; liquidation preference $152,637,776 as of December 31, 2023 |  |  | — |  |  |  | 152,464,599 |
Stockholders’ and Members’ Equity: |  |  |  |  |  |  |  |
Class A Common Stock, par value $0.0001 per share, 150,000,000 shares authorized, 40,560,433 shares issued and outstanding as of December 31, 2024 |  |  | 4,056 |  |  |  | — |
Class C Common Stock, par value $0.0001 per share, 70,000,000 shares authorized, 25,994,400 shares issued and outstanding as of December 31, 2024 |  |  | 2,599 |  |  |  | — |
Additional paid-in capital |  |  | 226,722,424 |  |  |  | — |
Accumulated other comprehensive loss |  |  | (5,803,378 | ) |  |  | (4,859,933 | )
Accumulated deficit |  |  | (191,047,953 | ) |  |  | (146,389,367 | )
Noncontrolling interest |  |  | 19,891,093 |  |  |  | — |
Total Equity (Deficit) |  |  | 49,768,841 |  |  |  | (151,249,300 | )
Total Liabilities and Equity |  | $ | 83,086,591 |  |  | $ | 33,692,933 |

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

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ALEANNA, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE LOSS
FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

|  | For the Year Ended December 31,
|  | 2024 |  | 2023
Revenues |  | $ | 1,420,030 |  |  | $ | — |
Operating expenses: |  |  |  |  |  |  |  |
Cost of revenues |  | $ | 1,043,174 |  |  | $ | — |
General and administrative |  |  | 6,264,087 |  |  |  | 5,634,150 |
Depreciation |  |  | 133,516 |  |  |  | — |
Accretion of asset retirement obligation |  |  | 133,239 |  |  |  | 133,239 |
Business Combination transaction expenses |  |  | 8,398,653 |  |  |  | — |
Total operating expenses |  |  | 15,972,669 |  |  |  | 5,767,389 |
Operating loss |  |  | (14,552,639 | ) |  |  | (5,767,389 | )
Other income (expense): |  |  |  |  |  |  |  |
Interest and other income (expense) |  |  | 1,948,281 |  |  |  | (102,041 | )
Change in fair value of derivative liability |  |  | 173,177 |  |  |  | 708,869 |
Total other income (expense) |  |  | 2,121,458 |  |  |  | 606,828 |
Net loss |  | $ | (12,431,181 | ) |  | $ | (5,160,561 | )
Deemed dividend to Class 1 Preferred Units redemption value |  |  | (155,423,177 | ) |  |  | (53,219,200 | )
Net loss attributable to noncontrolling interests |  |  | 87,511 |  |  |  | — |
Net loss attributable to Class A Common stockholders or holders of Common Member Units |  | $ | (167,766,847 | ) |  | $ | (58,379,761 | )
Other comprehensive income (loss) |  |  |  |  |  |  |  |
Currency translation adjustment |  |  | (1,548,154 | ) |  |  | 218,908 |
Comprehensive loss |  |  | (13,979,335 | ) |  |  | (4,941,653 | )
Comprehensive loss attributable to noncontrolling interests |  |  | 87,511 |  |  |  | — |
Total comprehensive loss attributable to Class A Common stockholders |  | $ | (13,891,824 | ) |  | $ | (4,941,653 | )
Weighted average shares of Class A Common Stock outstanding, basic and diluted |  |  | 38,286,170 |  |  |  | 31,643,646 |
Net loss per share of Class A Common Stock, basic and diluted |  | $ | (4.38 | ) |  | $ | (1.84 | )

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

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ALEANNA, INC.
CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ AND MEMBERS’ EQUITY
FOR THE YEARS ENDED DECEMBER 31, 2024 and 2023

|  | Temporary Equity |  | Members’ Equity
|  | Class 1 Preferred Units |  | Amount |  | Common Member Units |  | Amount |  | Additional Paid-in Capital |  | Accumulated Deficit |  | Accumulated Other Comprehensive Loss |  | Total Members’ Equity
Balance, December 31, 2022 |  | 22,606 |  | 78,241,267 |  | 266,503 |  | — |  | 13,173,784 |  |  | (101,183,390 | ) |  | (5,078,841 | ) |  | (93,088,447 | )
Shares issued |  | 21,004 |  | 21,004,132 |  | — |  | — |  | — |  |  | — |  |  | — |  |  | — |
Deemed dividend to redemption value |  | — |  | 53,219,200 |  | — |  | — |  | (13,173,784 | ) |  | (40,045,416 | ) |  | — |  |  | (53,219,200 | )
Foreign currency translation |  | — |  | — |  | — |  | — |  | — |  |  | — |  |  | 218,908 |  |  | 218,908 |
Net loss |  | — |  | — |  | — |  | — |  | — |  |  | (5,160,561 | ) |  | — |  |  | (5,160,561 | )
Balance, December 31, 2023 |  | 43,610 |  | 152,464,599 |  | 266,503 |  | — |  | — |  |  | (146,389,367 | ) |  | (4,859,933 | ) |  | (151,249,300 | )

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ALEANNA, INC.
CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ AND MEMBERS’ EQUITY — (CONTINUED)
FOR THE YEARS ENDED DECEMBER 31, 2024 and 2023

|  | Temporary Equity |  | Members’ Equity |  |  |  |  |  | Stockholders’ Equity
|  | Class 1 Preferred Units |  | Amount |  | Common Member Units |  | Amount |  | Class A Common Stock |  | Amount |  | Class C Common Stock |  | Amount |  | Additional Paid-in Capital |  | Accumulated Deficit |  | Accumulated Other Comprehensive Loss |  | Noncontrolling Interest |  | Total Stockholders’ Equity
Balance, December 31, 2023 |  | 43,610 |  |  | 152,464,599 |  |  | 266,503 |  |  | — |  | — |  | — |  | — |  | — |  | — |  | (146,389,367 | ) |  | (4,859,933 | ) |  | — |  |  | (151,249,300 | )
Shares issued |  | 62,100 |  |  | 62,100,000 |  |  | — |  |  | — |  | — |  | — |  | — |  | — |  | — |  | — |  |  | — |  |  | — |  |  | — |
Deemed dividend to redemption value |  | — |  |  | 155,423,177 |  |  | — |  |  | — |  | — |  | — |  | — |  | — |  | — |  | (155,423,177 | ) |  | — |  |  | — |  |  | (155,423,177 | )
Recapitalization transaction |  | (105,710 | ) |  | (369,987,776 | ) |  | (266,503 | ) |  | — |  | 40,560,433 |  | 4,056 |  | 25,994,400 |  | 2,599 |  | 226,722,424 |  | 123,108,261 |  |  | — |  |  | 20,156,904 |  |  | 369,994,244 |
Foreign currency translation |  | — |  |  | — |  |  | — |  |  | — |  | — |  | — |  | — |  | — |  | — |  | — |  |  | (943,445 | ) |  | (604,709 | ) |  | (1,548,154 | )
Net loss |  | — |  |  | — |  |  | — |  |  | — |  | — |  | — |  | — |  | — |  | — |  | (12,343,670 | ) |  | — |  |  | (87,511 | ) |  | (12,431,181 | )
Noncontrolling interest acquired |  | — |  |  | — |  |  | — |  |  | — |  | — |  | — |  | — |  | — |  | — |  | — |  |  | — |  |  | 426,409 |  |  | 426,409 |
Balance, December 31, 2024 |  | — |  |  | — |  |  | — |  |  | — |  | 40,560,433 |  | 4,056 |  | 25,994,400 |  | 2,599 |  | 226,722,424 |  | (191,047,953 | ) |  | (5,803,378 | ) |  | 19,891,093 |  |  | 49,768,841 |

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

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ALEANNA, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

|  | For the Year Ended December 31,
|  | 2024 |  | 2023
Cash flows from operating activities: |  |  |  |  |  |  |  |
Net loss |  | $ | (12,431,181 | ) |  | $ | (5,160,561 | )
Adjustments to reconcile net loss to net cash used in operating activities: |  |  |  |  |  |  |  |
Depreciation and amortization |  |  | 213,514 |  |  |  | — |
Impairment of assets |  |  | — |  |  |  | 30,786 |
Accretion of asset retirement obligation |  |  | 133,239 |  |  |  | 133,239 |
Change in fair value of derivative liability |  |  | (173,177 | ) |  |  | (708,869 | )
Changes in working capital items: |  |  |  |  |  |  |  |
Accounts receivable |  |  | (1,275,246 | ) |  |  | — |
Prepaid expenses and other assets |  |  | (1,251,773 | ) |  |  | (29,618 | )
Value-added tax refund receivable |  |  | (2,789,575 | ) |  |  | (1,418,231 | )
Accounts payable and accrued expenses |  |  | 1,281,916 |  |  |  | 878,675 |
Related party payables |  |  | (525,276 | ) |  |  | 525,276 |
Change in operating lease liability |  |  | (79,998 | ) |  |  | — |
Net cash used in operating activities |  |  | (16,897,557 | ) |  |  | (5,749,303 | )
Cash flows from investing activities |  |  |  |  |  |  |  |
Additions to renewable natural gas properties |  |  | (9,721,376 | ) |  |  | — |
Additions to conventional natural gas properties |  |  | (13,344,911 | ) |  |  | (8,924,941 | )
Net cash used in investing activities |  |  | (23,066,287 | ) |  |  | (8,924,941 | )
Cash flows from financing activities |  |  |  |  |  |  |  |
Proceeds from Business Combination |  |  | 648,122 |  |  |  | — |
Business Combination transaction expenses eligible for capitalization |  |  | (641,654 | ) |  |  | — |
AleAnna Energy Class 1 Preferred Units issued for cash |  |  | 62,100,000 |  |  |  | 21,004,132 |
Net cash provided by financing activities |  |  | 62,106,468 |  |  |  | 21,004,132 |
Effect of foreign currency translation on cash |  |  | (571,729 | ) |  |  | 135,698 |
Change in cash during the year |  |  | 21,570,894 |  |  |  | 6,465,586 |
Cash, beginning of year |  |  | 6,759,265 |  |  |  | 293,679 |
Cash, end of year |  | $ | 28,330,159 |  |  | $ | 6,759,265 |
Noncash investing and financing activities: |  |  |  |  |  |  |  |
Deemed dividend to Class 1 Preferred Units redemption value (see Note 10) |  | $ | (155,423,177 | ) |  | $ | (53,219,200 | )
Supplemental disclosures: |  |  |  |  |  |  |  |
Noncash recognition of new land lease (see Note 5) |  | $ | 1,882,275 |  |  |  | — |

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

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 1 — NATURE OF OPERATIONS AND RECENT EVENTS

AleAnna, Inc. (together with its subsidiaries, the “Company” or “AleAnna”), a Delaware corporation, was formed on December 13, 2024, in connection with the Business Combination (defined below). AleAnna Energy, LLC (“AleAnna Energy”), a Delaware Limited Liability Company, was formed on July 13, 2007. AleAnna Energy is comprised of wholly owned subsidiaries AleAnna Resources, LLC, AleAnna Italia S.p.A. and AleAnna Renewable Energy S.r.L. (“AleAnna Renewable”). AleAnna Renewable is comprised of various subsidiaries that hold its renewable natural gas assets (the “RNG Subsidiaries”).

Conventional Natural Gas

AleAnna is a development-stage natural gas resource company focused on delivering critical natural gas supplies to Europe through both onshore conventional natural gas exploration and renewable natural gas development in Italy. AleAnna has several conventional natural gas discoveries including the Longanesi field, located in the Po Valley in Northern Italy, which is one of Italy’s largest modern gas discoveries. AleAnna retains a 33.5% working interest in the Longanesi field with its working interest partner, and operator, Societa Padana Energia (“Padana”). AleAnna acquired its working interest in the Longanesi field through a 2016 transaction with Enel, accounted for as an asset acquisition. AleAnna also retains wholly owned concessions, permits, and pending applications on other exploration and development prospects across Italy which are supported by proprietary modern 3D seismic reservoir imaging. Planned principal operations have not yet commenced. As of December 31, 2024, the Company had not derived revenue from its conventional natural gas activities. AleAnna’s primary activities currently involve the drilling, testing, and tie-in of three Longanesi development wells together with its working interest partner, Padana. Tie-in of these wells and the installation of the temporary processing facility are complete. AleAnna and Padana achieved first production of the five wells in the Longanesi field in March 2025. The permanent processing facility is expected to be constructed over the course of 2025 and early 2026 and commissioned in mid-2026.

On October 29, 2024, the Company entered into a gas sale agreement (“GSA”) with Shell Energy Europe Limited (“SEEL”), whereby SEEL became the exclusive buyer of AleAnna’s share of the natural gas produced from the Longanesi field net of (i) any consumption and/or losses incurred in the transport, treatment and compression of gas before delivery; (ii) any volume to be allocated for regulated royalties auctions, if applicable; and (iii) any other volume contractually allocated to other parties before August 31, 2022. Future sales under the GSA are contingent upon the commencement of gas production.

Renewable Natural Gas (“RNG”)

In 2021, AleAnna launched a renewable natural gas (“RNG”) development business focused on bringing to market carbon negative renewable natural gas derived from animal and agricultural waste.

Between March 2024 and July 2024, the Company successfully completed three separate strategic acquisitions of renewable natural gas (“RNG”) assets in Italy for an aggregate of approximately $9.5 million. The plant assets are fully permitted and are in various stages of the development lifecycle, with one greenfield plant asset that is a new development (Campagnatico) and two brownfield plant assets (Casalino and Campopiano) that are currently operational. The Company plans to develop and upgrade these assets for RNG production in the future.

Campagnatico Asset Acquisition

On March 20, 2024, the Company closed the acquisition of the Campagnatico Greenfield (“Campagnatico”) natural gas asset in Tuscany, Italy for approximately $2.1 million. The greenfield site is fully permitted for future construction of a RNG plant asset.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 1 — NATURE OF OPERATIONS AND RECENT EVENTS (cont.)

Casalino and Campopiano Asset Acquisitions

On July 8, 2024, the Company closed the acquisition of the Societa Agricola Fattoria delle Jersey S.S. plant asset (“Casalino”) for approximately $3.6 million. On July 29, 2024, the Company closed the acquisition of a 90% interest in the Società Agricola Campopiano Società in nome collettivo di Vasellini Amedeo (“Compapiano”) plant asset for approximately $3.8 million. The plant assets are fully permitted for production of electricity through conversion of crop and animal waste bio feedstocks. The plant assets currently convert biomethane to electricity for sale. It is the company’s intention to begin upgrading the sites to refine biomethane into renewable natural gas through upgrading units. Following the upgrade process to transition the assets to biomethane to renewable natural gas conversion, the Company expects to sell renewable natural gas to customer(s) by trucking or piping the renewable natural gas to the interstate pipeline system (SNAM). Until the plant assets are upgraded, the Company will actively source bio feedstocks for the assets in order to produce biomethane which will be processed through reciprocating generators in order to generate electricity which is then sold onto the grid through a metered interconnection. Casalino and Campopiano derive revenues from the sale of such electricity to the local state-owned electrical utility (Gestore dei Servizi Energetici SpA or “GSE”) responsible for the purchase and marketing of energy produced by small-scale renewable energy assets. Energy generation revenue is recognized as the electricity generated by the Casalino and Campopiano assets is delivered to GSE. Revenues are based on actual output and a non-company specific predetermined price for small renewable energy producers of €280/MWh, established under Ministerial Decree (D.M.) 18 December 2008, which sets tariff rates for small renewable energy producers in Italy.

The Company has a 90% direct controlling interest in the Campopiano asset, while unaffiliated owners retain a 10% economic interest in the asset. The unaffiliated outside ownership in Campopiano is shown as noncontrolling interests (“NCI”) in stockholders’ equity in the Company’s consolidated financial statements.

AleAnna Energy Member Contributions

During 2024, AleAnna Energy received $62.1 million in capital contributions from its members, resulting in the issuance of 62,100 Class 1 Preferred Units, which have since been converted to Class A common stock and Class C common stock as a result of the Business Combination (see Note 2 below). These funds have been and will continue to be used to fund the Longanesi tie-in and permanent gas plant construction obligations, to develop and upgrade existing RNG assets, to acquire new RNG assets (at the discretion of management), as well as to fund general and administrative expenses of AleAnna and its subsidiaries.

NOTE 2 — REVERSE RECAPITALIZATION TRANSACTION

On December 13, 2024 (the “Closing Date”), the previously announced business combination was consummated pursuant to that certain Agreement and Plan of Merger (as amended by that certain First Amendment to the Merger Agreement, dated as of October 8, 2024, the “Merger Agreement”), dated June 4, 2024, by and among Swiftmerge Acquisition Corp., a Cayman Islands exempted company (“Swiftmerge”), Swiftmerge HoldCo LLC, a Delaware limited liability company and wholly-owned subsidiary of Swiftmerge (“HoldCo”), Swiftmerge Merger Sub LLC, a Delaware limited liability company and wholly-owned subsidiary of HoldCo (“Merger Sub”) and AleAnna Energy (the “Merger”). The transactions contemplated by the Merger Agreement are collectively referred to herein as the “Business Combination.”

The Business Combination included, among other things:

• (i) SPAC undergoing the Domestication and changing its name to “AleAnna, Inc.”; (ii) each Swiftmerge Class A Ordinary Share converting into one share of Class A Common Stock; (iii) each Swiftmerge Class B Ordinary Share converting into one share of Class B Common Stock in the Domestication and then each share of Class B Common Stock converting into one share of Class A Common Stock at the completion of the Business Combination; (iv) each warrant to purchase Swiftmerge Class A Ordinary Shares becoming exercisable by its terms to purchase an equal number of shares of Class A Common Stock; and (v) a series Class C Common Stock being authorized, each share of which will have voting rights equal to a share of Class A Common Stock but which shall have no entitlement to earnings or distributions of the Company;

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 2 — REVERSE RECAPITALIZATION TRANSACTION (cont.)

• following the Domestication but prior to the Merger, (i) the Company contributed to HoldCo (a) all of its assets (excluding its interests in HoldCo), including, for the avoidance of doubt, the Available Cash (as defined herein), and (b) a number of shares of Class C Common Stock equal to the number of Class C HoldCo Units designated to be issued to the AleAnna Members, and (ii) HoldCo issued to the Company a number of Class A HoldCo Units which equaled the number of shares of Class A Common Stock issued and outstanding immediately after the Closing; and

• following the Pre-Closing Contribution, Merger Sub merged with and into AleAnna Energy, with AleAnna Energy being the surviving company and a wholly-owned subsidiary of HoldCo. Each AleAnna Energy Member received its pro rata portion of 65,098,476 shares of (a) Class A Common Stock or (b) Class C Common Stock (with one Class C HoldCo Unit to accompany each share of Class C Common Stock) in the Merger, as determined by the AleAnna Energy Board. Nautilus, which owned approximately 97% of AleAnna Energy prior to the transaction, received 25,994,400 shares of Class C Common Stock and 25,994,400 Class C HoldCo Units in the Merger, as well as 37,134,194 shares of Class A Common Stock. The other AleAnna Energy Member, Bonanza Resources (Texas) Inc. received 1,969,882 shares of Class A Common Stock.

The Business Combination was accounted for as a common control transaction with respect to AleAnna Energy, which is akin to a reverse recapitalization. Nautilus Resources LLC (“Nautilus”), the majority owner of AleAnna Energy, had a controlling financial interest in AleAnna Energy prior to the Business Combination and has a controlling financial interest in the Company, as AleAnna Energy is a subsidiary of HoldCo, in which AleAnna, Inc. holds a majority economic interest. The net assets of Swiftmerge are stated at their historical carrying amounts with no goodwill or intangible assets recognized in accordance with U.S. GAAP. The Business Combination with respect to AleAnna Energy was not treated as a change in control primarily due to Nautilus receiving the controlling voting stake in the Company and the ability of Nautilus to nominate the full board of directors and management of the Company.

In accounting for the Business Combination, Swiftmerge was treated as the “acquired” company for financial reporting purposes. Accordingly, for accounting purposes, the Business Combination was treated as the equivalent of AleAnna Energy issuing stock for the net assets of Swiftmerge, accompanied by a recapitalization.

The Class A common stock, par value $0.0001 per share, of AleAnna, Inc. (the “Class A Common Stock”) and the 11,250,000 warrants issued as part of units in the initial public offering of Swiftmerge (the “Public Warrants”) commenced trading on Nasdaq under the symbols “ANNA” and “ANNAW,” respectively, on December 16, 2024. Each share of Class C Common Stock has voting rights equal to a share of Class A Common Stock but have no entitlement to earnings or distributions of AleAnna. Each share of Class C Common Stock is exchangeable, subject to certain conditions, for one share of Class A Common Stock. The exchange feature does not allow for cash settlement. AleAnna is organized in an “Up-C” structure effective with the Business Combination, and the only direct assets of AleAnna consist of equity interests in HoldCo, whose only direct assets consist of equity interests in AleAnna Energy. The Company’s business is conducted through AleAnna Energy and its subsidiaries.

Total proceeds raised from the Business Combination were $0.6 million, representing the proceeds from the Swiftmerge operating account after Swiftmerge public shareholder redemptions. These proceeds were offset by $9.5 million of transaction costs. Approximately $0.6 million of the transaction expenses were recorded as a reduction to additional paid-in capital (up to the amount of cash proceeds from the Business Combination). Approximately $0.5 million represented prepaid directors and officers insurance premiums and were recorded to prepaid expenses and other assets. The remaining $8.4 million of costs incurred were expensed and presented as Business Combination transaction expenses in the consolidated statement of operations for the year ended December 31, 2024.

As of December 31, 2024, no shares of Class C Common Stock had been exchanged for shares of Class A Common Stock.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 3 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation — The Company’s consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America (“U.S. GAAP”) as determined by the Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”).

These audited consolidated financial statements, in the opinion of management, reflect all adjustments (all of which are considered of a normal recurring nature) considered necessary to present fairly the Company’s financial position, results of operations and cash flows for the periods and dates presented.

Immaterial Restatement of Prior Period Financial Statements — In the fourth quarter of 2024, we identified an error in the classification of the contingent consideration liability and an error in the computation of foreign currency translation adjustments as of and for the year ended December 31, 2023. Refer to Note 16 for quantification of the prior period restatement impacts. Additionally, comparative prior period amounts in the applicable notes to the consolidated financial statements have been restated.

Principles of Consolidation — The Company’s policy is to consolidate all entities that the Company controls by ownership interest or other contractual rights giving the Company control over the most significant activities of an investee. The consolidated financial statements include the accounts of AleAnna and its wholly-owned subsidiaries HoldCo, AleAnna Energy, AleAnna Resources, LLC, AleAnna Italia S.p.A., AleAnna Renewable and the RNG Subsidiaries. All intercompany balances and transactions have been eliminated in consolidation.

Use of Estimates — The preparation of consolidated financial statements in conformity with accounting principles U.S GAAP requires management to make estimates and assumptions that affect the reported amounts of expenses, assets, and liabilities and disclosure of contingent assets and liabilities. The Company regularly assesses these estimates; however, actual amounts could differ from those estimates. The most significant items involving management’s estimates include estimates of contingencies including contingent consideration and estimates of the timing and amount of asset retirement obligations. The impact of changes in estimates is recorded in the period in which they become known.

Emerging Growth Company — The Company is an “emerging growth company,” as defined in Section 2(a) of the Securities Act, as modified by the Jumpstart Our Business Startups Act of 2012 (the “JOBS Act”), and it may take advantage of certain exemptions from various reporting requirements that are applicable to other public companies that are not emerging growth companies including, but not limited to, not being required to comply with the auditor attestation requirements of Section 404 of the Sarbanes-Oxley Act of 2002, reduced disclosure obligations regarding executive compensation in its periodic reports and proxy statements, and exemptions from the requirements of holding a nonbinding advisory vote on executive compensation and stockholder approval of any golden parachute payments not previously approved.

Further, Section 102(b)(1) of the JOBS Act exempts emerging growth companies from being required to comply with new or revised financial accounting standards until private companies (that is, those that have not had a Securities Act registration statement declared effective or do not have a class of securities registered under the Exchange Act) are required to comply with the new or revised financial accounting standards. The JOBS Act provides that an emerging growth company can elect to opt out of the extended transition period and comply with the requirements that apply to non-emerging growth companies but any such an election to opt out is irrevocable. The Company has elected not to opt out of such extended transition period, which means that when a standard is issued or revised and it has different application dates for public or private companies, the Company, as an emerging growth company, can adopt the new or revised standard at the time private companies adopt the new or revised standard. This may make comparison of the Company’s consolidated financial statements with another public company that is neither an emerging growth company nor an emerging growth company that has opted out of using the extended transition period difficult because of the potential differences in accounting standards used.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 3 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (cont.)

Risks and Uncertainties — The Company is currently in the development stage and has not yet commenced principal operations or generated revenue from its conventional natural gas business. The development of the Company’s projects is subject to a number of risks and uncertainties including, but not limited to, the receipt of the necessary permits and regulatory approvals, commodity price risk impacting the decision to go forward with the projects, and the availability and ability to obtain the necessary financing for the development of projects.

The Company’s ability to develop and operate commercial production facilities, as well as expand production at future commercial production facilities, is subject to many risks beyond its control, including regulatory developments, construction risks, and global and regional macroeconomic developments.

Functional and Reporting Currency — The functional currency of an entity is the currency of the primary economic environment in which the entity operates. The functional currency of the Italian subsidiary is the Euro, and the Company is the United States Dollar (“USD” or “U.S. Dollar”). The determination of functional currency was made in accordance with 830, Foreign Currency Matters.

The Company’s reporting currency is the USD. For the purposes of presenting consolidated financial statements, the assets and liabilities of the Company’s Euro operations are translated to USD at the exchange rate at the end of each month prior to consolidation procedures. The income and expenses are translated using average exchange rates for the applicable period. Foreign currency differences that arise on translation for consolidated purposes are recognized in accumulated other comprehensive loss on the consolidated balance sheet and in other comprehensive loss as a currency translation adjustment on the consolidated statements of operations and comprehensive loss.

Concentration of Credit Risk — Financial instruments that potentially subject the Company to concentrations of credit risk consist of cash accounts in financial institution which, at times may exceed the Federal Depository Insurance Corporation coverage limit of $250,000 in the U.S. or the Interbank Deposit Protection Fund limit of €100.000 in Italy. However, the majority of the Company’s cash and cash equivalents are held with a U.S.-based global systemically important financial institution. The Company has not experienced losses on these accounts, and management believes the Company is not exposed to significant credit risk on such balances.

Business Combinations and Asset Acquisitions — To evaluate whether an acquiree meets the definition of a business, the Company first applies a screen test to determine if substantially all of the fair value of the gross assets acquired is concentrated in a single identifiable asset or group of similar identifiable assets. If the screen test is met, the transaction is accounted for as an asset acquisition. If the screen test is not met, the Company further considers whether the set of assets acquired have, at a minimum, inputs and processes that have the ability to create outputs in the form of revenue. If the assets acquired meet this criteria, the transaction is accounted for as a business combination.

Acquisitions that qualify as an asset acquisition are accounted for using a cost accumulation model where the purchase price of the acquisition is allocated to the assets acquired on a relative fair value basis on the date of acquisition. The Company generally accounts for acquisitions of RNG assets as asset acquisitions. Inputs used to determine such fair values are primarily based upon internally-developed estimates, estimates developed by third-party valuation firms, and publicly-available data regarding RNG asset transactions consummated by other buyers and sellers, as applicable. These fair values are considered Level 3 assets in the fair value hierarchy. Any associated acquisition costs are generally capitalized.

Acquisitions that qualify as a business combination are accounted for using the acquisition method of accounting. The fair value of consideration transferred for an acquisition is allocated to the assets acquired and liabilities assumed based on their fair value on a nonrecurring basis on the acquisition date and are subject to fair value adjustments under certain circumstances. The excess of the consideration transferred over the fair value of assets acquired and liabilities assumed is recorded as goodwill. Conversely, in the event the fair value of assets acquired and liabilities assumed is greater than the consideration transferred, a bargain purchase gain is recognized.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 3 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (cont.)

Determining the fair value of assets acquired and liabilities assumed requires judgment and often involves the use of significant estimates and assumptions as fair values are not always readily determinable. Different techniques may be used to determine fair values, including market prices (where available), comparisons to transactions for similar assets and liabilities and the discounted net present value of estimated future cash flows, among others. The Company engages third-party valuation firms when appropriate to assist in the fair value determination of assets acquired and liabilities assumed. Acquisition-related expenses and transaction costs associated with business combinations are expensed as incurred. The Company may adjust the amounts recognized in an acquisition during a measurement period not to exceed one year from the date of acquisition, as a result of subsequently obtaining additional information that existed at the acquisition date.

Where applicable, asset acquisitions may be owned together with unaffiliated outside parties. In acquisitions where the Company has majority direct controlling interest, the unaffiliated outside ownership is shown as noncontrolling interests (“NCI”) in stockholders’ equity in the Company’s consolidated financial statements.

Cash and Cash Equivalents — Cash and cash equivalents represent cash and short-term, highly liquid investments with maturities of three months or less at the time of purchase. The Company had $28.3 million of cash equivalents as of December 31, 2024. The Company did not have any cash equivalents as of December 31, 2023.

Financial Instruments — The carrying values of the Company’s financial instruments, consisting of cash and cash equivalents and accounts payable, approximate their fair value due to the short maturity of such instruments. Unless otherwise noted, it is management’s opinion that the Company is not exposed to significant interest or currency risks arising from these financial instruments.

Fair Value Measurement — The Company applies fair value accounting to all financial assets and liabilities measured on a recurring and nonrecurring basis. Fair value is defined as an exit price, representing the amount that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. As such, fair value is a market-based measurement that should be determined based on assumptions that market participants would use in pricing an asset or a liability.

The accounting guidance establishes a fair value hierarchy based on three levels of inputs, of which the first two are considered observable and the last unobservable, used to determine the fair value of its financial instruments. A financial instrument’s level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement.

|  | Level 1 |  | Quoted prices in active markets for identical assets or liabilities that the entity has the ability to access.
|  | Level 2 |  | Inputs other than Level 1 that are observable, either directly or indirectly, such as quoted prices for similar assets or liabilities, quoted prices in markets that are not active, or other inputs that are observable or can be corroborated by observable market data for substantially the full term of the assets and liabilities.
|  | Level 3 |  | Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets and liabilities.

In some circumstances, the inputs used to measure fair value might be categorized within different levels of the fair value hierarchy. In those instances, the fair value measurement is categorized in its entirety in the fair value hierarchy based on the lowest level input that is significant to the fair value measurement.

Conventional Natural Gas Properties — The Company uses the successful efforts method of accounting for gas producing activities. Under this method, the cost of productive wells and related equipment, development dry holes, and any permits related to productive acreage are capitalized, and depleted using the unit-of-production method.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 3 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (cont.)

These costs include other internal costs directly attributable to production activities. AleAnna is not yet recognizing depletion as assets are not yet producing and therefore have not yet been placed in service. Costs for exploratory dry holes, exploratory geological and geophysical activities, and delay rentals as well as other property carrying costs are charged to exploration expense.

There were no exploratory wells drilled and there were no capitalized exploratory well costs incurred during the years ended December 31, 2024 and 2023. All asset additions in 2024 and 2023 relate to the drilling and testing of three incremental Longanesi development wells. All five Longanesi wells began production in March 2025.

The estimates of proved natural gas reserves (“SEC Case”) utilized in the preparation of the Consolidated Financial Statements are estimated in accordance with the rules established by the Securities and Exchange Commission (“the SEC”) and the FASB. These rules require that reserve estimates be prepared under existing economic and operating conditions using a trailing 12-month average price with no provision for price and cost escalations in future years except by contractual arrangements. The development of the Company’s natural gas reserve quantities requires management to make significant estimates and assumptions related to the intent and ability to complete undeveloped proved reserves within a five-year development period, as prescribed by SEC guidelines. Management engaged DeGolyer and MacNaughton, independent reserve engineers, to prepare reserves estimates for the Company’s estimated proved reserves at December 31, 2024 and 2023. The technologies used in the estimation of the Company’s net proved undeveloped reserves include, but are not limited to, empirical evidence through drilling results and well performance, production data, decline curve analysis, well logs, geologic maps, core data, seismic data, demonstrated relationship between geologic parameters and performance, and the implementation and application of statistical analysis.

Management has confirmed that none of the Unitized Operating Agreements (“UOAs”) nor the Proved Undeveloped Reserves (“PUDs”) are scheduled to be developed on a date more than five years from the date the reserves were initially recognized as PUDs as prescribed by the SEC guidelines. PUDs are converted from undeveloped to developed as applicable wells begin production.

Reserve estimates are inherently imprecise. Accordingly, the estimates are expected to change as more current information becomes available. Such estimates are subject to the uncertainties inherent in the application of judgmental factors in interpreting such information. It is possible that, because of changes in market conditions or the inherent imprecision of reserve estimates, the estimates of future cash inflows, future gross revenues, the amount of natural gas reserves, the remaining estimated lives of natural gas properties, or any combination of the above may be increased or decreased. Increases in recoverable economic volumes generally reduce per unit depletion rates, while decreases in recoverable economic volumes generally increase per unit depletion rates.

Impairment of Natural Gas Properties — The carrying values of the Company’s natural gas properties are reviewed for impairment when events or circumstances indicate that the remaining carrying value may not be recoverable. To determine whether impairment of the Company’s natural gas properties has occurred, the Company compares the estimated expected undiscounted future cash flows to the carrying values of those properties. Estimated future cash flows are based on proved and, if determined reasonable by management, risk-adjusted probable reserves and assumptions generally consistent with the assumptions used by the Company for internal planning and budgeting purposes, including, among other things, the intended use of the asset, anticipated production from reserves, future market prices for natural gas adjusted for basis differentials, future operating costs and inflation. Proved gas properties that have carrying amounts in excess of estimated future undiscounted cash flows are written down to fair value, which is estimated by discounting the estimated future cash flows using discount rates and other assumptions that marketplace participants would use in their fair value estimates. The company recorded no impairment of natural gas properties during 2024 or 2023.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 3 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (cont.)

Value-Added Tax Refund Receivable — The Valued-Added Tax (“VAT”) is a broadly-based consumption tax that is assessed to the value that is added to goods and services. The VAT applies to nearly all goods and services that are bought and sold within the European Union. Italian law allows for certain VAT payments to be recovered through ongoing applications for refunds. The Company has incurred higher VAT input paid (i.e., VAT paid on purchases) than the VAT output collected (i.e., VAT collected on sales), resulting in a net VAT refund receivable.

Under Italian tax law, VAT refunds receivable may be refunded in cash or applied against future taxes liabilities. Given the legal framework ensuring recoverability of these amounts, management believes the risk of non-collection is minimal, and therefore no reserve for uncollectible amounts is applied against the receivable.

Leases — The Company recognizes right-of-use assets and lease liabilities for leases with terms greater than 12 months. Leases are classified as either finance or operating leases. This classification dictates whether lease expense is recognized based on an effective interest method or on a straight-line basis over the term of the lease.

Short-term leases (leases with an initial term of 12 months or less or leases that are cancelable by the lessee and lessor without significant penalties) are not capitalized but are expensed on a straight-line basis over the lease term.

Credit Losses — The Company uses a forward-looking expected credit loss model for in-scope financial assets. Provisions for credit losses that are estimated through the Company’s prescribed method of estimating losses are recorded against earnings through a corresponding entry to Allowance for Credit Losses. Financial assets are presented net of the Allowance for Credit Losses. Any recoveries of amounts previously estimated as a credit loss are recorded against Allowance for Credit Losses.

In accordance with ASC 326, Financial Instruments — Credit Losses, the Company estimates the allowance for credit losses using relevant available information about expected credit losses. Inputs to the model include benchmarking against other companies, customer attributes, past events, current conditions, and reasonable and supportable forecasts. Adjustments to historical loss information are made for differences in current receivable-specific risk characteristics such as changes in the economy and demand trends, or other relevant factors. The Company’s financial assets measured at amortized cost primarily consist of trade receivables.

The assessment of the correlation between historical losses, current conditions, and forecasted economic conditions requires judgment. Alternative interpretations of these factors could have resulted in different conclusions regarding the allowance for credit losses. The amount of credit loss is sensitive to changes in circumstances and forecasted economic conditions. The Company’s experience, current conditions, and forecast of economic conditions may also not be representative of the customers’ actual default experience in the future.

Income Taxes — The Company follows the asset and liability method of accounting for income taxes under ASC 740, “Income Taxes.” Deferred tax assets and liabilities are recognized for the estimated future tax consequences attributable to differences between the consolidated financial statements carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that included the enactment date. Valuation allowances are established, when necessary, to reduce deferred tax assets to the amount expected to be realized.

ASC 740 prescribes a recognition threshold and a measurement attribute for the financial statement recognition and measurement of tax positions taken or expected to be taken in a tax return. For those benefits to be recognized, a tax position must be more likely than not to be sustained upon examination by taxing authorities. The Company recognizes accrued interest and penalties related to unrecognized tax benefits as income tax expense. There were no unrecognized tax benefits and no amounts accrued for interest and penalties as of December 31, 2024 or 2023. The Company is currently not aware of any issues under review that could result in significant payments, accruals or material deviation from its position. The Company is subject to income tax examinations by major U.S. and Italian taxing authorities since inception.

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Table of Contents

ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 3 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (cont.)

Warrants and Derivative Liability — The Company accounts for the Public Warrants in accordance with the guidance contained in Accounting Standards Codification (“ASC”) 815, Derivatives and Hedging (“ASC 815”) under which the warrants meet the criteria for equity treatment and are recorded as equity. Such guidance provides that the Public Warrants are not precluded from equity classification because they are indexed to the Company’s own stock and do not require cash settlement. Additionally, the warrants meet the criteria for equity classification as they (i) do not provide the holder with rights that are contingently redeemable, (ii) are not considered to be freestanding derivatives requiring liability classification under ASC 480, and (iii) do not have terms that would require the Company to net cash settle the warrants. Equity-classified contracts are initially measured at fair value (or allocated value). Subsequent changes in fair value are not recognized as long as the contracts continue to be classified in equity. No Public Warrants had been exercised as of December 31, 2024.

The Company evaluates the existence of separable embedded features within applicable debt or equity instruments pursuant to ASC 815. Professional standards generally provide three criteria that, if met, require companies to bifurcate embedded features from their host instruments and separately account for them as derivative. These three criteria include circumstances in which (a) the economic characteristics and risks of the embedded derivative instrument are not clearly and closely related to the economic characteristics and risks of the host contract, (b) the hybrid instrument that embodies both the embedded derivative instrument and the host contract is not re-measured at fair value under otherwise applicable generally accepted accounting principles with changes in fair value reported in earnings as they occur and (c) a separate instrument with the same terms as the embedded derivative instrument would be considered a derivative instrument. See Note 7 for a discussion of the Company’s derivative liability that existed as of December 31, 2023, but was derecognized in conjunction with the Business Combination.

Asset Retirement Obligations — The Company recognizes a liability for asset retirement obligations (“AROs”) based on an estimate of the amount and timing of settlement at the time a legal obligation is incurred. Upon initial recognition of an ARO, the Company increases the carrying amount of the long-lived asset by the same amount as the liability.

The initial capitalized costs will be depleted over the useful (productive) lives of the related assets.

The Company’s asset retirement obligations relate to the abandonment of gas production facilities including reclaiming well pads, reclaiming water impoundments, plugging wells and dismantling related structures. Estimates are based on historical experience of plugging and abandoning wells and reclaiming or disposing other assets and estimated remaining (productive) lives of the wells and assets.

The following table presents a reconciliation of the beginning and ending carrying amounts of the Company’s asset retirement obligations included in non-current liabilities in the Consolidated Balance Sheets.

|  | December 31, 2024 |  | December 31, 2023
Balance January 1 |  | $ | 4,242,680 |  | $ | 3,847,784
Liabilities incurred |  |  | — |  |  | 261,657
Accretion |  |  | 133,239 |  |  | 133,239
Ending balance |  | $ | 4,375,919 |  | $ | 4,242,680

No incremental ARO liabilities were incurred during the year ended December 31, 2024. For year ended December 31, 2023, the Company incurred incremental ARO liabilities, for one new development area associated with Longanesi (Casale Cocchi 1). Changes in ARO in 2024 only relate to the accretion of the existing liability. The Company does not have any assets that are legally restricted for purposes of settling these obligations. The incremental ARO liability incurred in 2023 was discounted to present value at a rate of 4.22%.

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Table of Contents

ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 3 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (cont.)

Contingent Consideration liability — The Company recognized a liability for the contingent consideration in accounting for the asset acquisition in accordance with ASC 450, Contingencies (“contingent consideration liability”) based on the Company’s assessment of probability of the occurrence of payment and deemed the liability estimable based on the formulaic nature. See Note 6 for more information.

Revenue Recognition — The Company follows the guidance of the ASC 606, Revenue from Contracts with Customers (“ASC 606”). The core principle underlying revenue recognition under ASC 606 is that revenue should be recognized as goods or services are transferred to customers in an amount that reflects the consideration to which the Company expects to be entitled. ASC 606 defines a five-step process to achieve recognition and mandates additional disclosure about the nature, amount, timing and uncertainty of revenues and cash flows arising from customer contracts, including significant judgments, and changes in judgments and assets recognized from costs incurred to obtain or fulfill a contract.

Renewable Natural Gas (“RNG”) — As of December 31, 2024, the Company primarily earns revenue through electricity generation revenue from the conversion of bio feedstocks to biomethane which is then converted to electricity through reciprocating generators. Such electricity is then delivered onto the grid through a metered interconnection and sold to the local state-owned electrical utility responsible for the purchase and marketing of energy produced by small-scale renewable energy assets. Upon delivery of the electricity to the grid, all performance obligations have been satisfied and energy generation revenue is recognized based on actual output and non-company specific predetermined prices for small renewable energy producers of €280/MWh (D.M. 18/12/2008).

Revenue is recognized over time as the Company transfers the electricity to the grid at a metered interconnection. The customer obtains control of the product upon delivery onto the electrical grid. The Company generally has a single performance obligation in its arrangements with its customers. The Company has no long-term contracts containing quantity or electricity volume production requirements and there is no variable consideration present in the Company’s performance obligations. Per ASC 606-10-25-27(a), delivery of units of power that are simultaneously received and consumed by the customer would satisfy the criteria in to be accounted for as a performance obligation satisfied over time and the same method would be used to measure the entity’s progress towards complete satisfaction of the performance obligation to transfer each distinct unit of power in the series to the customer. The Company’s performance obligation related to the sales of electricity are satisfied over time upon delivery to the customer. Revenue is measured as the amount of consideration the Company expects to receive in exchange for transferring its products. The Company applies a practical expedient in FASB ASC 606-10-55-18 applicable to its sales by assessing whether the Company’s right to consideration corresponds directly with the value to the Company’s customer (the “invoice practical expedient”). The Company concluded that pricing that corresponds to the value provided to the customer. Consideration for each transaction is based upon non-company specific predetermined prices for small renewable energy producers of €280/MWh, established under Ministerial Decree (D.M.) 18 December 2008, which sets tariff rates for small renewable energy producers in Italy. Payment terms are typically two months after the invoice date and there are no return or refund rights.

During the year ended December 31, 2024, all revenue was derived from a single source (sales of electricity) and a single customer (the local state-owned electrical utility). As of December 31, 2024, the Company had $1.2 million of revenue receivable related to electricity sales.

NOTE 4 — RECENTLY ISSUED ACCOUNTING PRONOUNCEMENTS

In November 2024, the FASB issued ASU 2024-03 to improve the disclosures about a public business entity’s expenses. The update requires more detailed information on expense components, such as inventory purchases, employee compensation, depreciation, amortization, and depletion, within commonly reporting categories like cost of sales, SG&A, and research and development. These amendments are effective for annual reporting periods beginning after December 15, 2026, and interim reporting periods beginning after December 15, 2027. The Company is currently evaluating the provisions of the amendments and the impact on its future consolidated statements and disclosures.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 4 — RECENTLY ISSUED ACCOUNTING PRONOUNCEMENTS (cont.)

In November 2023, the FASB issued ASU 2023-07 to enhance disclosures of significant expense and segment profitability categories and amounts for each of the Company’s reportable business segments. These enhanced disclosures apply to entities that have a single reportable segment. The Company adopted ASU 2023-07 as of December 31, 2024. As a result, although the Company only has a single reportable segment, it has included all disclosures required by the amendments in ASU 2023-07 as well as all existing segment disclosures in Topic 280. See Note 15 for more information.

In December 2023, the FASB issued ASU 2023-09 to improve disclosures and presentation requirements to the transparency of the income tax disclosures by requiring consistent categories and greater disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The amendments are effective in annual periods beginning after December 15, 2024, with early adoption permitted. The Company is currently evaluating the provisions of the amendments and the impact on its future consolidated financial statements and disclosures.

Other recent accounting pronouncements issued by the FASB, including its Emerging Issues Task Force, the American Institute of Certified Public Accountants, and the SEC did not or in management’s opinion will not have a material impact on the Company’s present or future consolidated financial statements.

NOTE 5 — LEASES, RIGHT-OF-USE ASSETS AND RELATED LIABILITIES

Leases to explore for or use minerals, oil, natural gas, and similar nonregenerative resources (see ASC 930, Extractive Activities — Mining, and ASC 932, Extractive Activities — Oil and Gas) are excluded from the scope of ASC 842, Leases. The Company has surface and use agreements for Longanesi, Gradizza, Trava, and Armonia in Italy. These agreements are directly related to accessing the subsurface minerals and are assessed as part of the oil and gas properties. As of December 31, 2023, all leases in AleAnna’s portfolio, in addition to its lease of office space, are short-term leases (12 months or less) and did not require recognition on the balance sheet.

In July 2024, in conjunction with the Casalino acquisition, AleAnna entered into a lease of the land that holds the biomethane processing and conversion asset utilized to produce electricity. The lease term is from July 1, 2024 through December 31, 2032, with an option to extend the lease until December 31, 2041. The annual rent is €278,200 and must be paid in advance in four installments by the end of each calendar quarter. The total rent for the lease term until December 31, 2032 is €2,364,700. As of December 31, 2024, the Company’s operating lease right of use assets totaled $1.8 million, short term lease liabilities totaled $0.2 million, and long-term lease liabilities totaled $1.7 million. The Company recognized $0.1 million of operating lease expense during the year ended December 31, 2024 which was included in cost of revenues as the land being leased is directly related to the production and sale of electricity at Casalino.

The Company does not have any borrowings; therefore, it does not have an incremental borrowing rate readily determinable, and there was no incremental borrowing rate implicit in the Casalino land lease. As such, the company utilized a discount rate of 7.709% to measure its lease liability. This represents the Company’s estimated incremental borrowing rate, determined using the 3-month EURIBOR rate of 3.709% as of July 2024, plus an estimated spread of 400 basis points (4.000%), to reflect the Company’s credit risk profile. This reflects best estimate of the rate of interest that the Company would have to pay to borrow an amount equal to the lease payments on a collateralized basis over a similar term.

NOTE 6 — CONTINGENT CONSIDERATION LIABILITY

On July 13, 2016, AleAnna Europa S.r.L., a former subsidiary of AleAnna Resources LLC (which was subsequently merged into AleAnna Italia S.p.A. in December 2022), purchased a 33.5% working interest in the Longanesi field, which was accounted for as an asset acquisition. Consideration paid included €7 million cash and up to €24 million of deferred consideration payable upon production of the Longanesi field. The deferred consideration is payable based on a formulaic calculation which is predominantly dependent on sales volumes and spot natural gas prices during the first 12 years of production (the “Earn-Out Period”). There will be no deferred consideration due if Longanesi is not developed and no deferred consideration due if average annual gas prices are less than €3.65/Mcf over the Earn-Out Period.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 6 — CONTINGENT CONSIDERATION LIABILITY (cont.)

In connection with the achievement of first production and related revenue generation at Longanesi, AleAnna will be required to reserve $3.1 million related to the contingent consideration liability due to Enel (see Note 17). These funds will be classified as restricted cash in future balance sheets and may be used to satisfy the contingent consideration liability as payments become due. Payments become due 14 months after the first day of the month following the date of first production.

The Company recognized a liability for the contingent consideration in accounting for the asset acquisition in accordance with ASC 450, Contingencies (the “contingent consideration liability”).

As of December 31, 2024 and 2023, the contingent consideration liability was recorded at $25.0 million and $26.5 million, respectively, with the entire balance classified as long-term since all payments are due more than one year after the respective balance sheet dates. The estimate of the contingent consideration liability was determined based on inputs including the following as of December 31, 2024, and 2023: futures prices for European natural gas, Euro to USD exchange rates of 1.04 and 1.12, respectively, and management’s future expected annual Longanesi production. AleAnna is required to make formulaic deferred consideration payments effectively equating to 20% to 50% of revenue based on certain European natural gas threshold prices. The calculation and timing of such payments are primarily driven by future expected Longanesi production, as modeled by DeGolyer and MacNaughton, as well as forward European natural gas prices.

Changes in the contingent consideration liability attributable to factors other than foreign currency exchange rates are recognized in the consolidated statement of operations. Changes in the contingent consideration liability attributable to foreign currency translation, are recognized in other comprehensive loss within the consolidated statement of operations and comprehensive loss. The change in the contingent consideration liability for all periods presented is attributable to changes in foreign exchange rates.

NOTE 7 — DERIVATIVE LIABILITY

As of December 31, 2023, the Company recorded a derivative liability associated with certain embedded features of the Company’s Class 1 Preferred Units which entitle holders to a payout of 3.5x times their investment in the event of a company sale transaction or redemption at the option of the Company (the “3.5x Redemption Feature”). Since the potential payoff upon occurrence of company sale transaction and redemption at the option of the Company are the same, the Company analyzed the features as a single embedded feature for bifurcation. Based on the Company’s analysis of the host contract pursuant to ASC 815 — Derivatives and Hedging, the Company has concluded the Class 1 Preferred Units represent a debt host. The embedded 3.5x Redemption Feature involves a substantial premium and is contingent upon occurrence of company sale transaction, thus is not clearly and closely related to the debt host contract.

Further, the feature meets the definition of a derivative and other criteria under ASC 815 and requires bifurcation and separate recognition from the host contract as a derivative.

Accordingly, the Company recorded a derivative liability representing the estimated fair value of the 3.5x Redemption Feature. Fair value is determined using a discounted cash flow model to isolate the excess fair value attributable to the 3.5x redemption above the 35% rate of return stated in the Class 1 Preferred Unit agreement. Further, the Company developed probability-weighted redemption scenarios which could occur during the time period in which a 3.5x payoff would be applicable, to determine the ultimate fair value. The derivative liability was adjusted to reflect fair value using these Level 3 inputs at each period end (i.e., measured on a recurring basis) with changes in fair value recorded in the consolidated statements of operations and comprehensive loss.

The derivative liability was $0.2 million as of December 31, 2023 but was derecognized in conjunction with the closing of the Business Combination as the related Class 1 Preferred Units were exchanged for AleAnna common stock.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 7 — DERIVATIVE LIABILITY (cont.)

The following is a summary of the assumptions used in calculating the estimated fair value of such derivative liability as of December 31, 2023:

|  | December 31, 2023
Range of assumed years of company sale transaction |  | 2024 to 2026
Range of probability weights of a company sale transaction occurring in a given year |  | 15% – 35%
Overall probability of company sale transaction occurring at any point in the future |  | 26%
Discount rate applied to company sale transaction scenarios |  | 35%
Discount rate for business valuation utilized in company sale transaction scenarios |  | 10%

NOTE 8 — NATURAL GAS PROPERTIES

Conventional Natural Gas Properties

A summary of conventional natural gas properties is as follows:

|  | December 31, 2024 |  | December 31, 2023
Natural gas properties |  |  | 56,977,091 |  |  |  | 45,478,907 |
Less: Accumulated Impairment |  |  | (22,998,077 | ) |  |  | (22,998,077 | )
Natural gas and other properties, net |  | $ | 33,979,014 |  |  | $ | 22,480,830 |

The Company uses the successful efforts method of accounting for conventional natural gas-producing activities. Under this method, the cost of productive wells and related equipment, development dry holes, and any permits related to productive acreage are capitalized and depleted using the unit-of-production method. No depletion was recorded in either period presented as the Company had not yet commenced production as of December 31, 2024.

Renewable Natural Gas Properties

As of December 31, 2024, renewable natural gas properties included $9.4 million of land, improvements and other assets related to the purchase of three renewable natural gas plant assets across Italy between March 2024 and July 2024. The estimated fair values of these assets at the date of acquisition are considered Level 3 assets in the fair value hierarchy. The brownfield renewable natural gas plant assets (Casalino and Campopiano) have average estimated useful lives of 20 years. All depreciation expense included in the Condensed Consolidated Statements of Operations relate to the Company’s renewable natural gas plant assets.

NOTE 9 — COMMITMENTS AND CONTINGENCIES

Participation Agreements

On June 26, 2009, the Company entered into a Participation Agreement with Societa Padana Energia (“Padana”) for the drilling of the “Longanesi 1 exploration well”, “San Potito concession” and “Abbadessee 1 exploration” collectively referred to as the “Longanesi field”.

The Unified Operating Agreement (“UOA”) was originally signed between ENI and Grove and dated September 26, 2009. However, Padana has succeeded ENI as the operator, and AleAnna has succeeded Grove as the non-operator.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 9 — COMMITMENTS AND CONTINGENCIES (cont.)

Under the UOA, AleAnna and Padana have agreed to develop the Longanesi field to optimize the economic value of the identified reserves. AleAnna and Padana entered the UOA with initial participating shares in the Longanesi field equal to 33.5% for AleAnna and 66.5% for Padana, with Padana appointed as the operator. Padana is obliged to maintain the accounting records concerning the operations under the UOA in compliance with the laws and generally accepted accounting practices followed in the Italian oil and gas industry.

AleAnna and Padana fund their respective working interest shares of the capital required for Longanesi development and will receive their respective shares of the production output from the unitized field. However, such working interest percentages may be subsequently amended as more certainty is obtained over the Gas Originally in Place (“GOIP”) through redetermination procedures prescribed by the UOA. The redetermination process evaluates the results of the current development drilling program (well logs, production tests, etc.) and other new data that may be gathered from time to time (such as 3D seismic imaging) to determine if changes in GOIP have changed the respective working interest percentages. If a redetermination process suggests GOIP changes, but AleAnna and Padana do not agree on revised working interest percentages, an independent third party will opine and set the revised working interest allocations. Adjustments to future production entitlements and capital contributions may be made accordingly. Cash payments may be made between the participants where there is insufficient production to true up contributions to date. If a true up of historical capital contributions is required as a result of redetermination, such capital true-up amounts will include an interest charge based on the nine-month Euro interbank offered rate (“Euribor”) and the date of the original capital contribution.

On October 26, 2023, Padana formally called for the First Redetermination process, as defined in the UOA, to begin. However, the outcome of this or any future redetermination, which may impact working interest percentages and require a capital contribution rebalancing, is highly uncertain and such amounts are not estimable at this time. Accordingly, AleAnna has not recorded any receivable from or payable to Padana related to the redetermination process.

Contingencies and Legal Proceedings

The Company is subject to loss contingencies related to litigation, claims, investigations and legal and administrative cases and proceedings arising in the ordinary course of business. The Company evaluates these contingencies on a regular basis and accrues a liability for such matters when the Company believes that a loss is probable, and the amount of the loss can be reasonably estimated. Any such accruals are adjusted thereafter as appropriate to reflect changed circumstances. In the event the Company determines that (i) a loss to the Company is probable, but the amount of the loss cannot be reasonably estimated, or (ii) a loss to the Company is less likely than probable but is reasonably possible, then the Company is required to disclose the matter herein, although the Company is not required to accrue such loss.

When able, the Company determines an estimate of reasonably possible losses or ranges of reasonably possible losses, whether in excess of any related accrued liability or where there is no accrued liability, for legal proceedings.

In instances where such estimates can be made, any such estimates are based on the Company’s analysis of currently available information and are subject to significant judgment and a variety of assumptions and uncertainties and may change as new information is obtained.

The ultimate outcome of the matters described below, such as whether the likelihood of loss is remote, reasonably possible, or probable, or if and when the range of loss is reasonably estimable, is inherently uncertain.

Furthermore, due to the inherent subjectivity of the assessments and unpredictability of outcomes of legal proceedings, any amounts accrued or estimated as possible losses may not represent the ultimate loss to the Company from the legal proceedings in question and the Company’s exposure and ultimate losses may be higher, and possibly significantly so, than the amounts accrued or estimated.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 9 — COMMITMENTS AND CONTINGENCIES (cont.)

As described in Note 1, AleAnna acquired a 33.5% working interest in the Longanesi field. As part of the purchase, a legacy owner, Blugas Infrastructure S.r.L. (“Blugas”), retained an interest akin to an overriding royalty interest (“ORRI”), whereby Blugas is entitled to physical delivery of 20% of the first 350 million standard cubic meters (“SCM”) produced from the Longanesi field. In accounting for the acquisition of the 33.5% working interest, the Company did not recognize an asset or liability in the consolidated financial statements related to the Blugas ORRI. Further, in December 31, 2023, the Company’s SEC Case reserves estimates contemplated the contractual arrangement and physical gas delivery to Blugas, such that the net cash flows related to the gas reserves attributable to the Company’s 33.5% working interest were reduced.

On May 28, 2024, the Company reached a settlement agreement (the “Blugas Settlement Agreement”) with Blugas regarding the Blugas ORRI. Under the terms of the Blugas Settlement Agreement, the Company paid Blugas approximately €5 million, plus an additional €1.1 million in applicable VAT, or approximately $6.6 million. In exchange, the Company was released from any future liability related to the Blugas ORRI. As a result of the transactions contemplated by the Blugas Settlement Agreement, the Company’s 33.5% working interest (net revenue interest) in the Longanesi field, as established under the terms of the Unified Operating Agreement arrangement originally signed between ENI and Grove and dated September 26, 2009, is now unencumbered except for normal government royalties (10%).

The Blugas Settlement Agreement was accounted for as an acquisition of the Blugas ORRI claim with a corresponding increase to the estimated future cash flows from our reserves. As such, the cost of the acquisition is included in natural gas and other properties, with the VAT portion included in value-added tax refund receivable in the consolidated balance sheet as of December 31, 2024. The Company’s year-end December 31, 2023 reserve quantities included the 20% of 350 million standard cubic meters (approximately 2,472 106ft3) allocable to the Blugas ORRI in the Company’s proved gas reserves. However, the required payments to Blugas associated with the sale of such quantities were reflected as cash outflows (costs) in the Company’s year-end December 31, 2023 reserve report as if such amounts were paid to Blugas. Following settlement, the Company’s year-end December 31, 2024 reserve quantities continue to include the 20% of 350 million standard cubic meters (approximately 2,472 106ft3); however, the previously required payments to Blugas associated with the sale of such quantities are no longer reflected as cash outflows (costs) given the acquisition of the Blugas ORRI. As the cash outflows (costs) are no longer reflected as if paid to Blugas, such amounts are reflected in the Company’s December 31, 2024 reserve report as allocable to the Company’s unencumbered 33.5% working interest.

NOTE 10 — EQUITY

AleAnna Common Stock and Noncontrolling Interests — As of December 31, 2024, the Company had 40,560,433 shares of Class A Common Stock outstanding and 25,994,400 shares of Class C Common Stock outstanding. See Note 2, Business Combination, for more details of the Company’s Class A Common Stock and Class C Common Stock as of December 31, 2024.

Following the Business Combination, holders of Class A Common Stock own a direct controlling economic interest in the results of the combined entity. Holders of Class C HoldCo Units and Class C Common Stock own an economic interest in the Company, shown as noncontrolling interests (“NCI”) in stockholders’ equity in the Company’s consolidated financial statements. Holders of Class C Common Stock have voting rights equal to holders of Class A Common Stock but no entitlement to earnings or distributions. The ownership interests of the Class A Common Stockholders and the NCI were 60.94% and 39.06%, respectively. The NCI may decrease as holders of Class C HoldCo Units (which represent an economic interest in HoldCo) and their corresponding shares of Class C Common Stock (which provide voting rights in AleAnna, Inc.) exchange both securities together for shares of Class A Common Stock. Each share of Class C Common Stock must be surrendered along with a corresponding Class C HoldCo Unit in order to receive one share of Class A Common Stock. As of December 31, 2024, no such exchanges had occurred.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 10 — EQUITY (cont.)

The financial statements also reflect NCI related to the 10% economic interest held in the Campopiano RNG asset by an unaffiliated third party, as discussed in Note 1.

Warrants — There were 11,250,000 Public Warrants outstanding as of December 31, 2024. Each warrant entitles the registered holder to purchase one share of Class A common stock at a price of $11.50 per share, subject to adjustment as discussed below, at any time commencing 30 days after the completion of our Business Combination.

The Company may call the Public Warrants for redemption:

• in whole and not in part;

• at a price of $0.01 per Public Warrant;

• upon not less than 30 days’ prior written notice of redemption (the “30-day redemption period”) to each Public Warrant holder;

• if, and only if, the reported last sale price of the Class A Common Stock equals or exceeds $18.00 per share (as adjusted for share splits, share capitalizations, reorganizations, recapitalizations and the like) on each of 20 trading days within a 30-trading day period ending on the third trading day before the Company sends the notice of redemption to the Public Warrant holders; and

• if, and only if, there is a current registration statement in effect with respect to the Class A Common Stock underlying such Public Warrants.

In the event that the Company elects to redeem all of the redeemable Public Warrants, its will fix a date for the redemption. Pursuant to the terms of the warrant agreement, notice of redemption will be mailed by first class mail, postage prepaid, by not less than 30 days prior to the redemption date to the registered holders of the redeemable Public Warrants to be redeemed at their last addresses as they appear on the registration books. Any notice mailed in the manner provided in the warrant agreement will be conclusively presumed to have been duly given whether or not the registered holder received such notice.

The Company has established the last of the redemption criterion discussed above to prevent a redemption call unless there is at the time of the call a significant premium to the Public Warrant exercise price. If the foregoing conditions are satisfied and the Company issues a notice of redemption of the Public Warrants, each Public Warrant holder will be entitled to exercise his, her or its Public Warrant prior to the scheduled redemption date. However, the price of the Class A Common Stock may fall below the $18.00 redemption trigger price (as adjusted for share splits, share capitalizations, reorganizations, recapitalizations and the like) as well as the $11.50 Public Warrant exercise price after the redemption notice is issued.

AleAnna Energy Equity (pre-Business Combination) — As of both December 13, 2024, immediately prior to the Business Combination, and as of December 31, 2023, the Company had 266,503 Common Units authorized, issued, and outstanding. The Common Units had no par value.

As of December 13, 2024, immediately prior to the Business Combination, and as of December 31, 2023, the Company had 105,711 and 43,610 shares of Class 1 Preferred Units authorized, issued, and outstanding, respectively. The Class 1 Preferred Units had no par value. The Class 1 Preferred Units were held by the majority equity owner, Nautilus.

Due to the redemption features of the Class 1 Preferred Units, they were recorded at redemption value and classified as temporary equity in the consolidated balance sheets as of December 31, 2023. The difference between the book value of Class 1 Preferred Units issued and the redemption value, less the amount attributable to the derivative liability discussed in Note 7, was recorded as a deemed dividend. AleAnna Energy’s Class 1 Preferred Units and Common Units were exchanged for AleAnna common stock in connection with the Business Combination (see Note 2).

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 11 — EXECUTIVE COMPENSATION

On September 1, 2022, the Company entered into an employment agreement with the CEO. Within this employment agreement, there is a Medium/Long Term Incentive Plan (“M/LTIP” or the “Plan”) outlined, which includes cash bonus amounts to be paid based on the completion of certain milestones within the established thresholds. Such payments could result in total payments ranging from €375,000 to €1,125,000. Threshold dates for such payments range from May 31, 2024, through December 31, 2026.

The Company tracks each of the milestones for the executive compensation package based on the current and future business plans. Based on the metrics and performance indicators outlined in the executive compensation package, management has identified that the likelihood of achieving each of these metrics is not probable based on the financial performance as of December 31, 2024.

NOTE 12 — INCOME TAXES

As of December 31, 2024, AleAnna, Inc. held 60.94% of the economic interest in HoldCo, which is treated as a partnership for U.S. federal income tax purposes. As a partnership, HoldCo generally is not subject to U.S. federal income tax under current U.S. tax laws as its net taxable income (loss) and any related tax credits are passed through to its members and included in their tax returns, even though such net taxable income (loss) or tax credits may not have actually been distributed. AleAnna, Inc. is subject to U.S. federal income taxes, in addition to state and local income taxes, with respect to its distributive share of the net taxable income (loss) and any related tax credits of HoldCo.

AleAnna Energy was historically and remains a disregarded subsidiary of a partnership for U.S. Federal income tax purposes with each partner being separately taxed on its share of taxable income or loss. As a direct result of the Business Combination, HoldCo became the sole member of AleAnna Energy. As such, HoldCo’s distributive share of any net taxable income or loss and any related tax credits of AleAnna Energy are then distributed to the Company.

For the days and periods prior to the closing of the Business Combination, AleAnna Energy was a disregarded subsidiary of an entity treated as a partnership. As such, its net taxable loss and any related tax credits were allocated to its members. The period as of and for the year ended December 31, 2024 discussed below represents the period beginning January 1, 2024 and ending December 31, 2024.

AleAnna’s Italian subsidiary (AleAnna Italia, S.p.A.) is a joint stock company or S.p.A and is considered a corporation under the Italian tax code. Therefore, the statutorily determined cumulative taxable loss of AleAnna Italia was tax affected and recognized as a deferred tax asset as of December 31, 2024 and December 31, 2023. The Company has also recorded deferred tax assets for temporary differences between the book and tax basis in the underlying assets and liabilities. Given AleAnna’s history of losses, and because future production remained uncertain as of December 31, 2024, a full valuation allowance was applied against the deferred tax assets. AleAnna Energy had no current or deferred income tax expense for the year ended December 31, 2023 due to its disregarded entity status.

The applicable U.S. and Italian corporate tax rates were 21% and 24%, respectively, and the effective tax rates were 0% during the years ended December 31, 2024 and 2023, given the losses incurred and the application of a full valuation allowance against deferred tax assets. Income (loss) before provision for income taxes consisted of the following:

|  | Years Ended December 31,
2024 |  | 2023
Domestic |  | $ | (8,732,939 | ) |  | $ | (742,017 | )
Foreign |  |  | (3,698,242 | ) |  |  | (4,418,544 | )
Total |  | $ | (12,431,181 | ) |  | $ | (5,160,561 | )

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Table of Contents

ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 12 — INCOME TAXES (cont.)

Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. The Company’s deferred tax assets as of the balance sheet dates were as follows:

|  | December 31, 2024 |  | December 31, 2023
Deferred tax assets: |  |  |  |  |  |  |  |
Net operating loss carryforwards |  | $ | 13,005,867 |  |  | $ | 11,128,340 |
Property and equipment |  |  | 17,955,431 |  |  |  | 2,414,550 |
Asset retirement obligation |  |  | 704,613 |  |  |  | 664,855 |
Contingent consideration |  |  | 5,980,895 |  |  |  | 6,065,049 |
Business Combination transaction expenses |  |  | 1,753,919 |  |  |  | — |
Investment in partnership |  |  | 5,381,564 |  |  |  | — |
Total deferred tax assets |  | $ | 44,782,289 |  |  | $ | 20,272,794 |
Valuation allowance |  |  | (44,489,087 | ) |  |  | (20,272,794 | )
Net deferred tax asset |  | $ | 293,202 |  |  | $ | — |
Deferred tax liabilities: |  |  |  |  |  |  |  |
Accounts receivable |  | $ | 293,202 |  |  | $ | — |
Other |  |  | — |  |  |  | — |
Total deferred tax liabilities |  |  | 293,202 |  |  |  | — |
Net deferred tax assets (liabilities) |  | $ | — |  |  | $ | — |

The Company has assessed the realizability of the net deferred tax assets, and in that analysis, has considered the relevant positive and negative evidence available to determine whether it is more likely than not that some portion or all of the deferred tax assets will be realized. In making such a determination, the Company considered all available positive and negative evidence, including future reversals of existing taxable temporary differences, projected future taxable income, tax planning strategies, and recent results of operations. After consideration of all available evidence, given AleAnna’s history of losses, and because future production remained uncertain as of December 31, 2024 and 2023, the Company recorded a full valuation allowance against its deferred tax assets as of December 31, 2024 and 2023. This valuation allowance will be maintained until there is sufficient evidence to support the reversal of all or some portion of these allowances. As noted above, the valuation allowances completely offset the deferred tax assets, which resulted in a net zero impact to the Company’s consolidated balance sheets as of December 31, 2024 and 2023.

As of December 31, 2024, the Company had a U.S. federal net operating loss (“NOL”) carryforward totaling $54.2 million, which does not expire.

The Company recognizes the financial statement effects of uncertain income tax positions when it is more likely than not, based on the technical merits, that the position will be sustained upon examination. To the extent the Company’s assessment of such tax positions changes, the change in estimate will be recorded in the period in which the determination is made. As of December 31, 2024 and 2023, the Company had not recorded any uncertain tax positions or accrued interest and penalties on the consolidated balance sheets.

The Company’s income tax filings will be subject to audit by various taxing jurisdictions. The Company will monitor the status of U.S. Federal, state and local income tax returns and Italian tax returns that may be subject to audit in future periods. No U.S. Federal, state and local income tax returns or Italian tax returns are currently under examination by the respective taxing authorities.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 13 — RELATED PARTY TRANSACTIONS

The Company follows FASB ASC subtopic 850-10, Related Party Disclosures, for the identification of related parties and disclosure of related party transactions.

As of December 31, 2023, AleAnna Energy had outstanding payables of $525,276, to its parent company, Nautilus, primarily related to the payment of legal fees by Nautilus on behalf of AleAnna. These intercompany payables are presented as related party payables on the accompanying condensed consolidated balance sheets and were settled in the normal course of business. Except for capital contributions received from Nautilus during the year ended December 31, 2024, and 2023, as presented in the consolidated statements of changes in shareholders’ and members’ equity, or as otherwise disclosed, there were no other related party transactions entered into during the periods presented that required recognition or disclosure.

NOTE 14 — LOSS PER SHARE

The Business Combination was accounted for as a common control transaction with respect to AleAnna Energy which is akin to a reverse recapitalization. This conclusion was based on Nautilus’s controlling financial interest in AleAnna Energy prior to the Business Combination and its continued control over the combined entit. Following the Business Combination, Nautilus holds Class A Common Stock, representing a direct controlling economic interest, and Class C HoldCo Units and Class C Common Stock, representing a noncontrolling economic interest classified as NCI in stockholders’ equity in the Company’s consolidated financial statements.

Given this change in equity structure and the requirements of ASC 260, Earnings per Share, the Company retrospectively adjusted its calculation of loss per share for the prior-year period to reflect the impact of the new capital structure in accordance with applicable reverse recapitalization guidance. As a result, the weighted average shares outstanding for the year ended December 31, 2023, were calculated by applying the implied conversion ratio from the Business Combination to the pre-merger AleAnna Energy LLC units, ensuring comparability with the post-Business Combination period.

Basic net loss per share has been computed by dividing net loss attributable to holders of Class A Common Stock by the weighted average number of shares of Class A Common Stock outstanding during the respective periods. Diluted earnings per share of Class A Common Stock was computed by dividing net loss attributable to holders of Class A Common Stock by the weighted-average number of shares of Class A Common Stock outstanding adjusted to give effect to potentially dilutive securities.

The Company’s potentially dilutive securities have been excluded from the computation of diluted net loss per share as the effect would be to reduce the net loss per share. Therefore, the weighted average number of shares of Class A Common Stock outstanding used to calculate both basic and diluted net loss per share is the same. The following table sets forth the computation of net loss used to compute basic net loss per share of Class A Common Stock for the years ended December 31, 2024 and 2023.

|  | Year Ended December 31,
2024 |  | 2023
Net loss attributable to Class A Common stockholders before deemed dividend |  | $ | (12,343,670 | ) |  | $ | (5,160,561 | )
Deemed dividend to AleAnna Energy Class 1 Preferred Units redemption value |  |  | (155,423,177 | ) |  |  | (53,219,200 | )
Income attributable to noncontrolling interests |  |  | 87,511 |  |  |  | — |
Net Loss attributable to holders of Class A Common Stock |  |  | (167,766,847 | ) |  |  | (58,379,761 | )
Weighted average shares of Class A Common Stock outstanding, basic and diluted |  |  | 38,286,170 |  |  |  | 31,643,646 |
Net loss per share of Class A Common Stock, basic and diluted |  | $ | (4.38 | ) |  | $ | (1.84 | )

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Table of Contents

ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 14 — LOSS PER SHARE (cont.)

The AleAnna Energy Class 1 Preferred Units were not considered to be participating based on their contractual rights. However, due to the redemption features of the Class 1 Preferred Units, they were recorded at redemption value and classified as temporary equity in the consolidated balance sheets prior to the Business Combination. The difference between the book value of Class 1 Preferred Units issued and the redemption value, less the amount attributable to the derivative liability discussed in note discussed in Note 7 prior to the Business Combination, was recorded as a deemed dividend. The deemed dividend reduced the net loss attributable to holders of Common Member Units (and subsequently holders of Class A Common Stock) in the calculation of the numerator above.

The 25,994,400 shares of Class C Common Stock and the 11,250,000 Public Warrants were not included in the calculation of diluted weighted average shares of Class A Common Stock outstanding as their inclusion would have been anti-dilutive. Shares of Class C Common Stock are not participating securities; thus, the application of the two-class method is not required.

NOTE 15 — SEGMENT REPORTING

The Company’s operations consist of one operating segment and reportable segment, reflecting the manner in which operations are managed and the criteria used by the chief operating decision maker (“CODM”), the Company’s Executive Chairman and Chief Executive Officer, collectively, to evaluate performance, develop strategy, and allocate resources.

AleAnna’s principal products include conventional natural gas produced from onshore exploration and development and RNG derived from animal and agricultural waste. The Company has not yet generated revenue from its conventional natural gas activities and has only recently begun deriving revenue from sales of electricity related to its RNG business.

While the Company has recently acquired three RNG assets, these assets are still in the early stages of development which may include expansion and installation of upgrading units to refine biomethane into renewable natural gas (rather than conversion to electricity). These assets have not generated significant revenues or incurred material expenses. As of, and for the period ending December 31, 2024, the Company’s CODM was primarily focused on capital investing decisions, strategy, and forward-looking investment economics. While the CODM monitors cash reserves and overall enterprise liquidity, extensive review and analysis of the Company’s performance and loss statements is not performed beyond review of the consolidated financial statements. As such, the CODM continues to assess the financial performance of the Company as a single enterprise on a consolidated basis, without distinguishing between conventional natural gas and RNG operations. Given the Company has not generated significant revenue or profits and is focused on development activities, the CODM does not utilize a specific measure of profit or loss to assess performance. The CODM does not monitor specific expense categories separately. The financial information reviewed by the CODM is consistent with the audited consolidated balance sheets and statements of operations and cash flows included herein.

All of the Company’s primary operating activities and assets remain located in Italy. The Company will continue to assess the need for including multiple reportable segments as the business evolves.

NOTE 16 — IMMATERIAL RESTATEMENT OF PRIOR PERIOD FINANCIAL STATEMENTS

Subsequent to the issuance of the Company’s consolidated financial statements as of and for the year ending December 31, 2023, errors were identified related to the classification of the contingent consideration liability and in the computation of foreign currency translation adjustments. As a result, the Company has restated the prior period financial statements and related disclosures to correct the errors. Management evaluated the materiality of the errors and concluded that they were not material, individually or in the aggregate, to the prior period financial statements. The Company will also correct previously reported financial information for such immaterial errors in future filings, as applicable.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 16 — IMMATERIAL RESTATEMENT OF PRIOR PERIOD FINANCIAL STATEMENTS (cont.)

The following tables reflect the effects of the corrections on all affected line items of the Company’s previously reported December 31, 2023 consolidated financial statements presented in this Form 10-K:

CONSOLIDATED STATEMENT OF OPERATIONS AND COMPREHENSIVE LOSS |  | December 31, 2023 Previously Reported |  | Correction |  | December 31, 2023 As Corrected
Operating expenses: |  |  |  |  |  |  |  |  |  |  |  |
Increase in contingent consideration liability |  | $ | 866,519 |  |  | $ | (866,519 | ) |  | $ | — |
Total operating expenses |  |  | 6,633,908 |  |  |  | (866,519 | ) |  |  | 5,767,389 |
Operating loss |  |  | (6,633,908 | ) |  |  | 866,519 |  |  |  | (5,767,389 | )
Net loss |  |  | (6,027,080 | ) |  |  | 866,519 |  |  |  | (5,160,561 | )
Net loss attributable to Common Member Units |  |  | (59,246,280 | ) |  |  | 866,519 |  |  |  | (58,379,761 | )
Other comprehensive income (loss) |  |  |  |  |  |  |  |  |  |  |  |
Currency translation adjustment |  |  | 135,698 |  |  |  | 83,210 |  |  |  | 218,908 |
Comprehensive loss |  | $ | (5,891,382 | ) |  | $ | 949,729 |  |  | $ | (4,941,653 | )

CONSOLIDATED BALANCE SHEET |  | December 31, 2023 Previously Reported |  | Correction |  | December 31, 2023 As Corrected
ASSETS |  |  |  |  |  |  |  |  |  |  |  |
Natural gas and other properties, successful efforts method |  | $ | 21,531,101 |  |  | $ | 949,729 |  |  | $ | 22,480,830 |
Total Non-current assets |  |  | 25,956,454 |  |  |  | 949,729 |  |  |  | 26,906,183 |
Total Assets |  | $ | 32,743,204 |  |  | $ | 949,729 |  |  | $ | 33,692,933 |
LIABILITIES AND MEMBERS EQUITY |  |  |  |  |  |  |  |  |  |  |  |
Current Liabilities: |  |  |  |  |  |  |  |  |  |  |  |
Contingent consideration liability, short-term |  | $ | 14,888,021 |  |  | $ | (14,888,021 | ) |  |  | — |
Total Current Liabilities |  |  | 16,640,293 |  |  |  | (14,888,021 | ) |  |  | 1,752,272 |
Non-current Liabilities: |  |  |  |  |  |  |  |  |  |  |  |
Contingent consideration liability, long-term |  |  | 11,594,021 |  |  |  | 14,888,021 |  |  |  | 26,482,042 |
Total Non-current Liabilities |  |  | 15,837,341 |  |  |  | 14,888,021 |  |  |  | 30,725,362 |
Members’ Equity: |  |  |  |  |  |  |  |  |  |  |  |
Accumulated other comprehensive loss |  |  | (4,943,143 | ) |  |  | 83,210 |  |  |  | (4,859,933 | )
Accumulated deficit |  |  | (147,255,886 | ) |  |  | 866,519 |  |  |  | (146,389,367 | )
Members Equity (Deficit) |  |  | (152,199,029 | ) |  |  | 949,729 |  |  |  | (151,249,300 | )
Total Liabilities, Temporary Equity, and Members’ Equity |  | $ | 32,743,204 |  |  | $ | 949,729 |  |  | $ | 33,692,933 |

CONSOLIDATED STATEMENT OF CASH FLOWS |  | December 31, 2023 Previously Reported |  | Correction |  | December 31, 2023 As Corrected
Cash flows from operating activities: |  |  |  |  |  |  |  |  |  |  |  |
Net loss |  | $ | (6,027,080 | ) |  | $ | 866,519 |  |  | $ | (5,160,561 | )
Adjustments to reconcile net loss to net cash used in operating activities: |  |  |  |  |  |  |  |  |  |  |  |
Change in fair value of contingent consideration |  | $ | 866,519 |  |  | $ | (866,519 | ) |  | $ | — |
Net cash used in operating activities |  | $ | (5,749,303 | ) |  | $ | — |  |  | $ | (5,749,303 | )

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 17 — SUBSEQUENT EVENTS

The Company evaluated subsequent events and transactions that occurred after the balance sheet date up to March 31, 2025, the date that the financial statements were issued.

Warrant Exercises

In January and February 2025, holders exercised an aggregate 24,022 Public Warrants, resulting in the issuance 24,022 shares of Class A Common Stock at an exercise price of $11.50 per share. These exercises generated approximately $0.3 million in cash proceeds.

First Production at Longanesi

On March 13, 2025, AleAnna achieved a key milestone with the first production from its five wells in the Longanesi field.

In connection with this milestone, AleAnna will be required to reserve $3.1 million related to the contingent consideration liability due to Enel (see Note 6). These funds will be classified as restricted cash in future balance sheets and may be used to satisfy the contingent consideration liability as payments become due.

NOTE 18 — CONVENTIONAL NATURAL GAS PRODUCING ACTIVITIES (UNAUDITED)

The following supplemental information presents the results of natural gas activities in accordance with the successful efforts method of accounting.

The following table presents capitalized costs related to the development of natural gas discoveries (primarily the Longanesi field). See Note 8 for aggregate capitalized costs.

|  | For the Year Ended December 31,
2024 |  | 2023
Capitalized costs |  |  |  |  |  |
Proved properties |  | $ | 11,498,184 |  | $ | 9,091,621
Less: Accumulated depreciation and depletion |  |  | — |  |  | —
Net capitalized costs |  | $ | 11,498,184 |  | $ | 9,091,621

The following table presents costs incurred for acquisition of properties, exploration costs and development costs. As the Company’s primary activities in 2023 and 2024 involved the development of the Longanesi field, and there were no new acquisitions and minimal exploration activities, the primary costs incurred during 2023 and 2024 were development costs.

|  | For the Year Ended December 31,
2024 |  | 2023
Acquisition of properties |  | $ | 5,207,800 |  | $ | —
Exploration costs |  |  | — |  |  | —
Development costs |  |  | 6,290,384 |  |  | 9,091,621

The $5.2 million in acquisition of properties in the table above is related to the Blugas Settlement Agreement discussed in further detail in Note 9.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 18 — CONVENTIONAL NATURAL GAS PRODUCING ACTIVITIES (UNAUDITED) (cont.)

Reserve Information

Proved developed reserves represent only those reserves expected to be recovered from existing wells and support equipment. Proved undeveloped reserves represent proved reserves expected to be recovered from new wells after substantial development costs are incurred.

The net reserve information disclosed herein encompasses only the Company’s proved undeveloped Gradizza, Longanesi, and Trava discoveries. Other probable and possible reserves related to Gradizza, Longanesi, and Trava have been excluded. Other prospective resources related to AleAnna’s additional exploration prospects beyond Gradizza, Longanesi, and Trava have also been excluded. The following table summarizes estimated net natural gas reserves in millions of cubic feet.

|  | December 31, 2024 |  | December 31, 2023
|  | (10 6 ft 3)
Natural gas |  |  |  |  |
Proved developed and undeveloped reserves: |  |  |  |  |
Balance at January 1 |  | 17,689 |  |  | 13,778
Revision of previous estimates |  | — |  |  |
Due to extensions(1) |  | — |  |  | 3,911
Due to discoveries(1) |  | — |  |  | —
Due to changes in sales prices(1) |  | — |  |  | —
Due to other revisions(1) |  | (68 | ) |  | —
Balance at December 31 |  | 17,621 |  |  | 17,689
Proved developed reserves: |  |  |  |  |
Balance at January 1 |  | — |  |  | —
Balance at December 31 |  | — |  |  | —
Proved undeveloped reserves: |  |  |  |  |
Balance at January 1 |  | 17,689 |  |  | 13,778
Revision of previous estimates |  |  |  |  |
Due to extensions(1) |  | — |  |  | 3,911
Due to discoveries(1) |  | — |  |  | —
Due to changes in sales prices(1) |  | — |  |  | —
Due to other revisions(1) |  | (68 | ) |  | —
Balance at December 31 |  | 17,621 |  |  | 17,689

____________

(1) The slight decrease during the year ended December 31, 2024 due to other revisions was primarily related to the expected timing of forecasted startup dates for Longanesi and Gradizza. Increases from extensions during the year ended December 31, 2023 were solely related to the Company’s recent Longanesi development drilling. Recent drilling activity consisted of the drilling and completion of one gross Longanesi development well and workover and completion of one additional Longanesi development well (0.335 net to AleAnna’s interest) during the year ended December 31, 2023. The 3,911 106ft3 of reserves added during the year ended December 31, 2023 relate to the drilling and completion of one gross Longanesi development well (0.335 net to AleAnna’s interest) during the year ended December 31, 2023. There were no other positive or negative revisions to reserves in 2023 other than the reserves added as a result of drilling. We had no other exploratory or development drilling during the years ended December 31, 2024, or 2023. AleAnna’s existing reserves were considered economic and were expected to be recovered at the volume-weighted average price attributable to the estimated proved reserves of $11.73 and $14.13 per thousand cubic feet of gas for the year ended December 31, 2024, and 2023. As a result, there were no revisions to volumes in either year as a result of changes in sales prices during the years ended December 31, 2024, and 2023. The Company also had no other additions during the years ended December 31, 2024, or 2023.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 18 — CONVENTIONAL NATURAL GAS PRODUCING ACTIVITIES (UNAUDITED) (cont.)

Standard Measure of Discounted Future Cash Flow

Future net cash flows represent projected revenues from the sale of proved reserves, net of production and development costs (including transportation and gathering expenses, operating expenses and production taxes). Revenues are based on a twelve-month unweighted average of the first-day-of-the-month pricing, without escalation. Future cash flows are reduced by estimated production costs, administrative costs, costs to develop and produce the proved reserves and abandonment costs, all based on current economic conditions at each year-end. There can be no assurance that the proved reserves will be produced in the future or that prices, production or development costs will remain constant. There are numerous uncertainties inherent in estimating reserves and related information.

Management cautions that the standard measure of discounted future cash flows should not be viewed as an indication of the fair market value of natural gas producing properties, nor of the future cash flows expected to be generated. The information presented does not give recognition to future changes in estimated reserves, selling prices or costs and has been discounted at a rate of 10%. Further, the Company’s December 31, 2023 SEC Case reserves estimates contemplated the contractual arrangement and physical gas delivery to Blugas, such that the net cash flows attributable to the Company’s 33.5% working interest were reduced, as previously discussed in Note 9. Following settlement, the Company’s year-end December 31, 2024 reserve quantities continue to include the 20% of 350 million standard cubic meters (approximately 2,472 106ft3), however, the previously required payments to Blugas associated with the sale of such quantities are no longer reflected as cash outflows (costs) as if such amounts were paid to Blugas. As the cash outflows (costs) are no longer reflected as if paid to Blugas, such amounts are reflected in the Company’s December 31, 2024 reserve report as allocable to the Company’s unencumbered 33.5% working interest.

The following table summarizes the estimated future net cash flows from natural gas reserves (in thousands). All amounts noted relate to the Company’s onshore Italian gas assets. The Company has no other gas assets in other jurisdictions.

|  | December 31, 2024 |  | December 31, 2023
&NegativeThickSpace;Consolidated entities: |  |  |  |  |  |  |  |
Future cash inflows(1) |  |  | 206,696 |  |  |  | 249,944 |
Future production and development costs(1) |  |  | (76,363 | ) |  |  | (117,452 | )
Future income tax expenses(1) |  |  | (22,793 | ) |  |  | (41,888 | )
Future net cash flows |  |  | 107,540 |  |  |  | 90,604 |
10% annual discount for estimated timing of cash flows |  |  | (18,507 | ) |  |  | (20,680 | )
Standardized measure of discounted future net cash flows |  | $ | 89,033 |  |  | $ | 69,924 |
Total consolidated interests in the standardized measure of discounted future cash flows |  | $ | 89,033 |  |  | $ | 69,924 |

____________

(1) Gas prices are based on a reference price. Gross gas price is calculated as the unweighted arithmetic average of the first day-of-the-month price for each month within a 12-month period prior to the end of the reporting period. The volume-weighted average price attributable to the estimated proved reserves was $11.73 and $14.13 per thousand cubic feet of gas for the year ended December 31, 2024, and 2023, respectively. Future net cash flows were computed using the volume-weighted average price used in estimating AleAnna’s proved gas reserves, year-end costs, and statutory tax rates that relate to existing proved gas reserves.

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ALEANNA, INC.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
AS OF AND FOR THE YEARS ENDED DECMBER 31, 2024 AND 2023

NOTE 18 — CONVENTIONAL NATURAL GAS PRODUCING ACTIVITIES (UNAUDITED) (cont.)

The following table summarizes the aggregate change in the standardized measure of discounted future net cash flows for individually significant sources of change (in thousands).

|  | December 31, 2024 |  | December 31, 2023
Beginning standardized measure of discounted future net cash flows |  | $ | 69,924 |  |  | $ | 90,474 |
Net change in sales prices related to future production(1) |  |  | (54,042 | ) |  |  | (96,635 | )
Net change due to extensions(2) |  |  | — |  |  |  | 51,044 |
Net change due to purchase of royalty interest(3) |  |  | 40,750 |  |  |  | — |
Previously estimated development costs incurred during the period |  |  | 7,015 |  |  |  | 3,281 |
Net change in income taxes |  |  | 19,095 |  |  |  | 21,579 |
Accretion of discount |  | $ | 6,291 |  |  | $ | 181 |
Aggregate change in the standardized measure of discounted future net cash flows(3) |  |  | 19,109 |  |  |  | (20,550 | )
Ending standardized measure of discounted future net cash flows |  | $ | 89,033 |  |  | $ | 69,924 |

____________

(1) Gas prices are based on a reference price. Gross gas price is calculated as the unweighted arithmetic average of the first day-of-the-month price for each month within a 12-month period prior to the end of the reporting period. The volume-weighted average price attributable to the estimated proved reserves was $11.73 and $14.13 per thousand cubic feet of gas for the year ended December 31, 2024, and 2023, respectively.

(2) Increases from extensions are solely related to the Company’s recent Longanesi development drilling. Recent drilling activity consisted of the following: drilling and completion of one gross Longanesi development well and workover and completion of one additional Longanesi development well (0.335 net to AleAnna’s interest) during the year ended December 31, 2023. The 3,911 106ft3 of reserves added during the year ended December 31, 2023 relate to the drilling and completion of one gross Longanesi development well (0.335 net to AleAnna’s interest) during the year ended December 31, 2023. There were no other positive or negative revisions to reserves other than the reserves added as a result of drilling. The Company had no other exploratory or development drilling during the years ended December 31, 2024 or 2023. AleAnna’s existing reserves were considered economic and were expected to be recovered at the volume-weighted average price attributable to the estimated proved reserves of $11.73 and $14.13 per thousand cubic feet of gas for the year ended December 31, 2024, and 2023. As a result, there were no revisions to volumes in either year as a result of changes in sales prices during the years ended December 31, 2024 and 2023. The Company also had no other additions during the years ended December 31, 2024 or 2023.

(3) The Company’s December 31, 2023 SEC Case reserves estimates contemplated the contractual arrangement and physical gas delivery to Blugas, such that the net cash flows attributable to the Company’s 33.5% working interest were reduced, as previously discussed in Note 9. Following the purchase of the Blugas ORRI as discussed in Note 9, the Company’s year-end December 31, 2024 reserve quantities continue to include the 20% of 350 million standard cubic meters (approximately 2,472 106ft3). However, the previously required payments to Blugas associated with the sale of such quantities are no longer reflected as cash outflows (costs) as if such amounts were paid to Blugas. As the cash outflows (costs) are no longer reflected as if paid to Blugas, such amounts are reflected in the Company’s December 31, 2024 reserve report as allocable to the Company’s unencumbered 33.5% working interest.

(4) From December 31, 2022 to December 31, 2023, the standardized measure of discounted future net cash flows decreases as a result of lower prices as noted immediately above in footnote 1. The decrease in price more than offset the increase in reserves from extensions during the year ended December 31, 2023, resulting in a net decrease to the standardized measure of discounted future cash flows from December 31, 2022 to December 31, 2023. From December 31, 2023 to December 31, 2024, the standardized measure of discounted future net cash flows decreases as a result of lower prices as noted immediately above in footnote 1. The decrease in price more than offset the increase in reserves from extensions during the year ended December 31, 2024, resulting in a net decrease to the standardized measure of discounted future cash flows from December 31, 2023 to December 31, 2024.

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PART II

INFORMATION NOT REQUIRED IN PROSPECTUS

Item 13. Other Expenses of Issuance and Distribution.

The following table sets forth all costs and expenses, other than underwriting discounts and commissions, payable by us in connection with the Class A Common Stock being registered. All amounts shown are estimates except for the SEC registration fee.

|  | Amount Paid or to be Paid
SEC Registration Fee |  | $ | 19,807.31
Printing and miscellaneous expenses |  | $ | *
Legal fees and expenses |  | $ | *
Accounting fees and expenses |  | $ | *
Total: |  | $ | 19,807.31

____________

* These fees are calculated based on the securities offered and the number of issuances and accordingly cannot be defined at this time.

Item 14. Indemnification of Directors and Officers.

The registrant’s Certificate of Incorporation and Bylaws require it to indemnify any director, officer, employee or agent of the registrant who was or is a party to, or is threatened to be made a party to, or is otherwise involved in, any proceeding, by reason of the fact that he or she is or was a director, officer, employee or agent of the registrant or is or was serving at the request of the registrant as a director, officer, employee or agent of, or in any other capacity for, another corporation, partnership, joint venture, limited liability company, trust, or other enterprise, to the fullest extent permitted under Delaware law, against all expense, liability and loss (including attorneys’ fees, judgments, fines, taxes, penalties and amounts paid or to be paid in settlement) reasonably incurred or suffered by such person in connection with such proceeding if the person acted in good faith and in a manner reasonably believed to be in or not opposed to the best interests of the registrant and, with respect to any criminal action or proceeding, had no reasonable cause to believe his or her conduct was unlawful.

We have entered into agreements with our officers and directors to provide contractual indemnification in addition to the indemnification provided for in its Certificate of Incorporation and Bylaws. We have purchased a policy of directors’ and officers’ liability insurance that insures our officers and directors against the cost of defense, settlement or payment of a judgment in some circumstances and insures us against our obligations to indemnify our officers and directors.

The limitation of liability and indemnification provisions in these indemnification agreements and our Certificate of Incorporation and Bylaws may discourage stockholders from bringing a lawsuit against our directors for breach of fiduciary duty. These provisions also may reduce the likelihood of derivative litigation against our directors and officers, even though such an action, if successful, might otherwise benefit us and our stockholders. In addition, your investment in the registrant’s securities may be adversely affected to the extent we pay the costs of settlement and damage awards under these indemnification provisions.

Item 15. Recent Sales of Unregistered Securities.

During the three years preceding the filing of this registration statement on Form S-1, of which this prospectus is a part, AleAnna has granted or issued the following securities of AleAnna, which were not registered under the Securities Act.

• On December 13, 2024, AleAnna issued 25,994,400 shares of Class C Common Stock in connection with the close of the Business Combination. Such securities were issued pursuant to the exemption from registration contained in Section 4(a)(2) of the Securities Act.

• On January 18, 2022, the underwriter in Swiftmerge’s initial public offering partially exercised its over-allotment option and purchased an additional 2,500,000 units, at a price of $10.00 per unit, generating gross proceeds of $25,000,000. Simultaneously with the partial exercise of the over-allotment option,

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Swiftmerge sold an additional 750,000 private placement warrants to Sponsor, generating gross proceeds to the company of $750,000. Such securities were issued pursuant to the exemption from registration contained in Section 4(a)(2) of the Securities Act.

The sales of the above securities were exempt from the registration requirements of the Securities Act in reliance on the exemptions afforded by Section 4(a)(2) of the Securities Act.

Item 16. Exhibits and Financial Statement Schedules.

See the Exhibit Index immediately following the signature page hereto, which is incorporated by reference as if fully set forth herein.

Item 17. Undertakings.

(a) The undersigned registrant hereby undertakes:

(1) To file, during any period in which offers or sales are being made, a post-effective amendment to this Registration Statement:

(i) To include any prospectus required by section 10(a)(3) of the Securities Act;

(ii) To reflect in the prospectus any facts or events arising after the effective date of this Registration Statement (or the most recent post-effective amendment thereof) which, individually or in the aggregate, represent a fundamental change in the information set forth in the registration statement. Notwithstanding the foregoing, any increase or decrease in volume of securities offered (if the total dollar value of securities offered would not exceed that which was registered) and any deviation from the low or high end of the estimated maximum offering range may be reflected in the form of prospectus filed with the SEC pursuant to Rule 424(b) if, in the aggregate, the changes in volume and price represent no more than 20% change in the maximum aggregate offering price set forth in the “Calculation of Registration Fee” table in the effective registration statement; and

(iii) To include any material information with respect to the plan of distribution not previously disclosed in this Registration Statement or any material change to such information in this Registration Statement;

provided, however, that paragraphs (a)(1)(i), (ii), (iii) above do not apply if the registration statement is on Form S-1 and the information required to be included in a post-effective amendment by those paragraphs is contained in reports filed with or furnished to the SEC by the registrant pursuant to section 13 or section 15(d) of the Exchange Act that are incorporated by reference in the registration statement or is contained in a form of prospectus filed pursuant to Rule 424(b) that is part of the registration statement.

(2) That, for the purpose of determining any liability under the Securities Act of 1933, each such post-effective amendment shall be deemed to be a new registration statement relating to the securities offered therein, and the offering of such securities at that time shall be deemed to be the initial bona fide offering thereof.

(3) To remove from registration by means of a post-effective amendment any of the securities being registered which remain unsold at the termination of the offering.

(4) That, for the purpose of determining liability under the Securities Act of 1933 to any purchaser: each prospectus filed pursuant to Rule 424(b) as part of a registration statement relating to an offering, other than registration statements relying on Rule 430B or other than prospectuses filed in reliance on Rule 430A (§230.430A of this chapter), shall be deemed to be part of and included in the registration statement as of the date it is first used after effectiveness. Provided, however, that no statement made in a registration statement or prospectus that is part of the registration statement or made in a document incorporated or deemed incorporated by reference into the registration statement or prospectus that is part of the registration statement will, as to a purchaser with a time

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of contract of sale prior to such first use, supersede or modify any statement that was made in the registration statement or prospectus that was part of the registration statement or made in any such document immediately prior to such date of first use.

(5) that, for the purpose of determining liability of the registrant under the Securities Act to any purchaser in the initial distribution of the securities, the undersigned registrant undertakes that in a primary offering of securities of the undersigned registrant pursuant to this Registration Statement, regardless of the underwriting method used to sell the securities to the purchaser, if the securities are offered or sold to such purchaser by means of any of the following communications, the undersigned registrant will be a seller to the purchaser and will be considered to offer or sell such securities to such purchaser:

(a) any preliminary prospectus or prospectus of the undersigned registrant relating to the offering required to be filed pursuant to Rule 424;

(b) any free writing prospectus relating to the offering prepared by or on behalf of the undersigned registrant or used or referred to by the undersigned registrant;

(c) the portion of any other free writing prospectus relating to the offering containing material information about the undersigned registrant or its securities provided by or on behalf of an undersigned registrant; and

(d) any other communication that is an offer in the offering made by the undersigned registrant to the purchaser.

(b) Insofar as indemnification for liabilities arising under the Securities Act of 1933, may be permitted to directors, officers and controlling persons of the registrant pursuant to the foregoing provisions, or otherwise, the registrant has been advised that in the opinion of the SEC such indemnification is against public policy as expressed in the Act and is, therefore, unenforceable. In the event that a claim for indemnification against such liabilities (other than the payment by the registrant of expenses incurred or paid by a director, officer or controlling person of the registrant in the successful defense of any action, suit or proceeding) is asserted by such director, officer or controlling person in connection with the securities being registered, the registrant will, unless in the opinion of its counsel the matter has been settled by controlling precedent, submit to a court of appropriate jurisdiction the question whether such indemnification by it is against public policy as expressed in the Act and will be governed by the final adjudication of such issue.

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EXHIBIT INDEX

Item 18. Exhibits

Exhibits |  | Description
2.1† |  | Agreement and Plan of Merger, dated as of June 4, 2024, by and among Swiftmerge, HoldCo, Merger Sub and AleAnna (incorporated by reference to Exhibit 2.1 to the Company’s Registration Statement on Form S-4 (File No. 333-280699) filed with the Securities and Exchange Commission on July 5, 2024).
2.2 |  | First Amendment to Agreement and Plan of Merger, dated as of October 8, 2024, by and among Swiftmerge, HoldCo, Merger Sub and the Company (incorporated by reference to Exhibit 2.2 to the Company’s Registration Statement on Form S-4/A (File No. 333-280699) filed with the Securities and Exchange Commission on October 8, 2024).
3.1 |  | Certificate of Incorporation of AleAnna, Inc. (incorporated by reference to Exhibit 3.1 of the Company’s Current Report on Form 8-K (File No. 001-41164), filed with the Securities and Exchange Commission on December 19, 2024).
3.2 |  | Bylaws of AleAnna, Inc. (incorporated by reference to Exhibit 3.2 of the Company’s Current Report on Form 8-K (File No. 001-41164), filed with the Securities and Exchange Commission on December 19, 2024).
4.1 |  | Specimen Warrant Certificate of Swiftmerge (incorporated by reference to Exhibit 4.3 of the Company’s Registration Statement on Form S-1/A (File No. 333-254633), filed with the Securities and Exchange Commission on October 4, 2021).
4.2 |  | Warrant Agreement, dated as of December 14, 2021, by and between Continental Stock Transfer & Trust Company and Swiftmerge (incorporated by reference to Exhibit 4.1 of the Company’s Current Report on Form 8-K (File No. 001-41164), filed with the Securities and Exchange Commission on December 20, 2021).
5.1* |  | Opinion of Haynes and Boone, LLP.
10.1 |  | Amended and Restated Letter Agreement, dated June 4, 2024, by and between Swiftmerge Holdings, LP, Swiftmerge and the Company (incorporated by reference to Exhibit 10.1 of the Company’s Current Report on Form 8-K (File No. 001-41164), filed with the Securities and Exchange Commission on December 19, 2024).
10.2 |  | Investment Management Trust Agreement, dated as of December 17, 2021, by and between Swiftmerge and Continental Stock Transfer & Trust Company (incorporated by reference to Exhibit 10.3 of the Company’s Current Report on Form 8-K (File No. 001-41164), filed with the Securities and Exchange Commission on December 20, 2021).
10.3 |  | Amended and Restated Limited Liability Company Agreement of HoldCo (incorporated by reference to Exhibit 10.15 of the Company’s Current Report on Form 8-K (File No. 001-41164), filed with the Securities and Exchange Commission on December 19, 2024).
10.4 |  | Form of Investor Letter, dated June 4, 2024, by and between Swiftmerge, certain qualified institutional buyers or institutional accredited investors and certain unaffiliated third-party investors (incorporated by reference to Exhibit 10.16 of the Company’s Current Report on Form 8-K (File No. 001-41164), filed with the Securities and Exchange Commission on December 19, 2024).
10.5 |  | Amended and Restated Registration Rights Agreement, dated as of December 13, 2024, by and among the Company, Swiftmerge Holdings, LP, Nautilus Resources LLC, and certain other persons named therein (incorporated by reference to Exhibit 10.17 of the Company’s Current Report on Form 8-K (File No. 001-41164), filed with the Securities and Exchange Commission on December 19, 2024).
10.6+ |  | Form of Indemnification Agreement for directors and executive officers of AleAnna, Inc. (incorporated by reference to Exhibit 10.18 of the Company’s Current Report on Form 8-K (File No. 001-41164), filed with the Securities and Exchange Commission on December 19, 2024).
10.7+ |  | Employment Agreement, dated as of September 1, 2022, by and between Marco Brun and AleAnna (incorporated by reference to Exhibit 10.25 to the Company’s Registration Statement on Form S-4/A (File No. 333-280699) filed with the Securities and Exchange Commission on November 5, 2024).
16.1 |  | Letter from Marcum LLP to the Securities and Exchange Commission dated December 18, 2025 (incorporated by reference to Exhibit 16.1 of the Company’s Current Report on Form 8-K (File No. 001-41164), filed with the Securities and Exchange Commission on December 19, 2024).
21.1 |  | Subsidiaries of the Company (incorporated by reference to Exhibit 21.1 of the Company’s Current Report on Form 8-K (File No. 001-41164), filed with the Securities and Exchange Commission on December 19, 2024).

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Table of Contents

Exhibits |  | Description
23.1** |  | Consent of Deloitte & Touche LLP, independent registered accounting firm for the Company.
23.2** |  | Consent of DeGolyer and MacNaughton.
23.4* |  | Opinion of Haynes Boone, LLP (included in Exhibit 5.1).
24.1* |  | Power of Attorney (included on the signature page of the Registration Statement on Form S-1 as filed with the Commission on January 13, 2025).
99.1 |  | Report of DeGolyer and MacNaughton, Summary of Reserves at December 31, 2024 (incorporated by reference to Exhibit 99.1 of the Company’s Annual Report on Form 10-K (File No. 001-41164), filed with the Securities and Exchange Commission on March 31, 2025).
101.INS |  | Inline XBRL Instance Document (the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document).
101.SCH |  | Inline XBRL Taxonomy Extension Schema Document.
101.CAL |  | Inline XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF |  | Inline XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB |  | Inline XBRL Taxonomy Extension Label Linkbase Document.
101.PRE |  | Inline XBRL Taxonomy Extension Presentation Linkbase Document.
104* |  | Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).
107* |  | Filing Fee Table.

____________

† Certain schedules or similar attachments to this exhibit have been omitted pursuant to Item 601(a)(5) of Regulation S-K. The Company agrees to provide a copy of any omitted schedule or similar attachment to the SEC upon request.

+ Indicates management contract or compensatory plan.

** Filed herewith.

* Previously filed.

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Table of Contents

SIGNATURES

Pursuant to the requirements of the Securities Act of 1933, the registrant certifies that it has reasonable grounds to believe that it meets all of the requirements for filing on Form S-1 and has duly caused this Post-Effective Amendment to be signed on its behalf by the undersigned, thereunto duly authorized, on April 16, 2025.

|  | AleAnna, Inc.
|  | By: |  | /s/ Tristan Yopp
|  | Name: |  | Tristan Yopp
|  | Title: |  | Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1933, as amended, this Registration Statement has been signed by the following persons in the capacities and on the dates indicated below.

Signature |  | Title |  | Date
/s/ Marco Brun |  | Chief Executive Officer and Director |  | April 16, 2025
Marco Brun |  | (Principal Executive Officer) |  |
/s/ Tristan Yopp |  | Chief Financial Officer |  | April 16, 2025
Tristan Yopp |  | (Principal Financial Officer) |  |
/s/ Charles Roscopf |  | Chief Accounting Officer |  | April 16, 2025
Charles Roscopf |  | (Principal Accounting Officer) |  |
* |  | Director |  | April 16, 2025
Graham van’t Hoff |  |  |  |
* |  | Director |  | April 16, 2025
William K. Dirks |  |  |  |
* |  | Director |  | April 16, 2025
Duncan Palmer |  |  |  |
* |  | Director |  | April 16, 2025
Curtis Hébert |  |  |  |

*By: |  | /s/ Tristan Yopp |  |
Name: |  | Tristan Yopp, Attorney-in-Fact |  |

II-6

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