Tamboran Resources Corp: Form 10-K for the period ended Jun 30, 2026

Investing in our common stock involves risks. You should carefully consider the information in this report, including the matters addressed under “Cautionary Note Regarding Forward-Looking Statements,” the following risks and all of the other information set forth in this report before making an investment decision. The risks and uncertainties described below are not the only ones we face. Additional risks not presently known to us or that we currently deem immaterial may also impair our business operations. If any of the following risks actually occur, our business, financial condition and results of operations could be materially and adversely affected, and we may not be able to achieve our goals. We cannot assure you that any of the events discussed in the risk factors below will not occur. The trading price of our common stock could decline due to any of these risks, and you may lose all or part of your investment.

Risks Related to Our Business and Industry

We are an early stage development company with no material revenue expected until after initial gas sales, which commenced in September 2026. We have a limited operating history, and our future performance is uncertain. Our ability to successfully drill and complete the wells identified for our current capital plan will depend on a variety of factors.

We are an early stage development company with no material revenues or reserves currently. To date we have drilled eight horizontal wells as operator, six of which have been completed, with two wells (SS1-4H and SS1-6H) drilled and awaiting completion and a ninth well (SS1-2H) currently being drilled. We have observed lower normalized flow rates in one well compared to other wells that we have participated in drilling in the Beetaloo. We currently only have five wells tied into the SPCF. Companies in the early stages of operations face substantial business risks and may suffer significant losses. We face challenges and uncertainties in financial planning as a result of the unavailability of historical data and uncertainties regarding the nature, scope and results of our future activities. In the event that our drilling program is delayed, our operating results will be adversely affected, and our operations will differ materially from the activities described in this report.

Our business strategy includes importing and successfully utilizing U.S. drilling and completion techniques to the Northern Territory. We may not be successful in implementing that strategy or in completing the development of the infrastructure necessary to conduct our business as planned. Our ability to successfully maximize the benefits of U.S. technology and techniques depends on a variety of factors, including avoiding delays in procuring equipment and the ability to attract and train employees qualified to operate with U.S. best practices. As a result, we cannot assure you that we will achieve a rate of drilling success that is in line with, or even comparable to, expectations for natural gas development in the United States.

Our business plan requires substantial additional capital, which we may be unable to raise on acceptable terms in the future, or at all, which may in turn limit our ability to execute on our plans.

We have working interests in three wells that we are currently drilling, and estimate gross expenses of approximately $25 million to drill and complete each of those wells. Our ability to raise the capital required to fund the various phases of our development plan will depend on many factors, including:

• our success in attracting third party strategic and financial partners and investors to significantly fund our upstream and midstream development goals;
• the scope, rate of progress and cost of our development activities;
• natural gas prices;
• our ability to produce natural gas from our properties;
• the terms and timing of any drilling and other production-related arrangements that we may enter into;
• the infrastructure available and developed near our properties;
• the cost and timing of governmental approvals and/or concessions; and
• the effects of competition by other companies operating in the oil and natural gas industry.

We do not currently have any commitments for future external funding, and we do not expect to generate any revenue from production until after initial gas sales which commenced in September 2026, and will depend upon successful drilling results, additional and timely capital funding, further regulatory approvals, and access to suitable infrastructure. Additional financing may not be available on favorable terms, or at all. Even if we succeed in selling additional securities to raise funds, at such time the ownership percentage of our existing stockholders would be diluted, and new investors may demand rights, preferences or privileges senior to those of existing stockholders. If we raise additional capital through debt financing, the financing may involve covenants that restrict our business activities. If we choose to farm-out interests in our property, we may lose operating control over such property.

In addition, limitations on new share issuances under ASX rules may limit or prevent us from raising additional capital by issuing and selling shares of common stock or other securities when such additional capital is required. See “Our ability to raise additional capital may be significantly limited by listing rules of the ASX that limit the amount of common stock that we are permitted to issue without stockholder approval.”

Our business plan contemplates delivering natural gas to the Northern Territory, the Australian East Coast as well as select markets in South and East Asia. Our ability to deliver natural gas in significant quantities to these markets depends on the construction of additional pipeline capacity. We cannot assure you that we will be able to secure sufficient take-away capacity on our timing or at all.

The anticipated production from our business plan will exceed the capacity of the existing pipeline infrastructure that services the Beetaloo. We cannot assure you that we will reach a mutually satisfactory agreement with APA Group for the construction of the required take-away capacity or the satisfaction of the conditions of any such obligation. The delivery of the BEC Pipeline Project will be the subject of a future development agreement and the gas transport services will be the subject of a future gas transportation agreement. The failure to contract for the construction of additional take-away capacity will adversely affect the ability to execute our proposed business plan. In addition, even if we are able to contract for sufficient take-away capacity, we may not be able to contract for gathering and compression services, storage facility capacity, and interconnections to the major pipelines.

We have no proved reserves at this time and areas that we decide to drill may not yield natural gas in commercial quantities or quality, or at all.

We presently have no proved reserves and have not sold any natural gas produced. We did not have any revenue during the reporting period with first gas sales commencing in September 2026. Based on petrophysical analysis, we have identified locations and drilled appraisal wells that indicate prospective resources. However, our appraisal wells may not be indicative of future results. Additionally, the areas we have drilled, or may decide to drill in the future, may not yield natural gas in commercial quantities or quality, or at all. All of our current property is undeveloped and in various stages of evaluation that will require substantial additional seismic data reprocessing and interpretation. Accordingly, we do not know if our properties will contain natural gas in sufficient quantities or quality to recover drilling and completion costs or to be economically viable. Even if natural gas is found on our property in commercial quantities, construction costs of natural gas pipelines, associated infrastructure, and transportation costs may prevent such property from being economically viable.

Additionally, the analogies drawn by us from available data from other wells may not prove valid in respect of additional wells on our property. If a significant portion of our property does not prove to be successful, our business, financial condition and results of operations will be materially adversely affected.

We face substantial uncertainties in estimating the characteristics of our property, so you should not place undue reliance on any of our estimates.

In this report, we provide estimates of the characteristics of our properties, such as implied production volumes (including our 2.0 Bcf/d gross production goal and the normalization of initial production rates to longer lateral lengths), in the Beetaloo. These estimates may be incorrect, as the accuracy of these estimates is a function of the available data, geological interpretation and our judgment. We may not achieve our 2.0 Bcf/d gross production goal on our proposed timeline or at all, and the wells we have drilled or will drill may not achieve ultimate recoveries within the ranges we have estimated. To date, nine wells on our property have been drilled with us as an operator. Any analogies drawn by us from other wells or producing fields may not prove to be accurate indicators of the success of developing reserves from our property. Furthermore, we have no way of evaluating the accuracy of the data from analog wells or properties produced by other parties that we may use. Any significant variance between actual results and our assumptions could materially affect the quantities of natural gas attributable to any particular group of properties.

Drilling wells is speculative, often involving significant costs that may be more than our estimates, and may not result in any discoveries or additions to our future production or reserves. Any material inaccuracies in drilling costs, estimates or underlying assumptions will materially affect our business.

Exploring for and developing natural gas reserves involves a high degree of operational and financial risk, which precludes definitive statements as to the time required and costs involved in reaching certain objectives. The budgeted costs of drilling, completing and operating wells are often exceeded and can increase significantly when drilling costs rise due to a tightening in the supply of various types of natural gas field equipment and related services. Drilling may be unsuccessful for many reasons, including geological conditions, weather, cost overruns, equipment shortages and mechanical difficulties. Exploratory and appraisal wells bear a much greater risk of loss than development wells. Moreover, the successful drilling of a natural gas well does not necessarily result in a profit on investment. For example, during the drilling operations in the Shenandoah South Pilot Project, a downhole mechanical issue in SS2-2H led to it being plugged and sidetracked, SS2-2H-ST1, despite achieving a record horizontal section in the Middle Velkerri B Shale. Additionally, the completion operations for the SS2-5H well were paused due to detected stress in the casing connection, necessitating reinforcement activities before stimulation and completion activities were undertaken in 2026. A variety of factors, both geological and market-related, can cause a well to become uneconomic or only marginally economic. Our initial drilling sites, and any potential additional sites that may be developed, require significant additional exploration and development, regulatory approval and commitments of resources prior to commercial development. If our actual drilling and development costs are significantly more than our estimated costs, we may not be able to continue our business operations as proposed and we would be forced to modify our plan of operation.

We intend to import and implement U.S. practices and technology for use in the development of our properties in the Northern Territory. There is limited experience with these practices and technology within the workforce in the areas we operate. The ability to attract and train a qualified workforce could hamper our present operations and limit our ability to grow.

Our operations are mechanically complex and must be performed in remote geographic locations. We believe that our success depends upon our ability to employ and retain a sufficient number of technical personnel who have the ability to utilize, enhance and maintain our natural gas development equipment. Our ability to maintain and expand our operations depends in part on our ability to utilize, replace, supplement and increase our skilled labor force. The supply of skilled workers is limited in the Beetaloo, and it is not guaranteed that we will be able to access a sufficient skilled labor force. A significant increase in the wages paid by competing employers domestically and abroad could result in a reduction of our skilled labor force or cause an increase in the wage rates that we must pay or both. Employee turnover may also lead to lost productivity and decrease employee engagement, which could adversely impact our business.

Additionally, our ability to hire, train and retain qualified personnel may become more challenging as we grow and to the extent energy industry market conditions are competitive. Our ability to successfully implement U.S. practices and technology is dependent on finding, training and retaining qualified personnel within Australia for work in the Northern Territory. When general industry conditions are favorable, the competition for experienced operational and field technicians increases as other energy and manufacturing companies’ needs for the same personnel increases. Our ability to grow or even to continue our current level of operations could be adversely impacted if we are unable to successfully hire, train and retain these important personnel. In addition, effective succession planning for our employees and expansion planning are important to our long-term success. Failure to achieve these plans could hinder our strategic planning and execution and have a material adverse impact on our business, financial condition or results of operations.

Our inability to access appropriate equipment and infrastructure in a timely manner may hinder our access to natural gas markets and delay the phases of our business plan.

Our ability to market our natural gas will depend substantially on the availability and capacity of gathering systems, pipelines and processing facilities owned and operated by third parties not within our control. Our failure to obtain such services on acceptable terms could materially harm our business. The success of our business plan depends on importing and implementing U.S. practices and technology for use in the development of our properties in the Northern Territory. The delivery of the further drilling rigs may be delayed or canceled, and we may not be able to gain continued access to suitable rigs in the future. We may be required to shut in natural gas wells because of the absence of a market or because access to pipelines, gathering systems or processing facilities may be limited or unavailable. If that were to occur, then we would be unable to realize revenue from those wells until arrangements were made to deliver the production to market, which could cause significant delays to the phases of our business plan and have a material adverse effect on our results of operations and financial condition.

In the Beetaloo, as our development is in its preliminary stage, we have no binding agreements for the gathering and processing of our potential future production. As a result, our business plan is dependent on third parties to develop the infrastructure for our natural gas gathering needs. Capital constraints could limit the construction of new pipelines and gathering systems. Until this new capacity is available, we may experience delays in producing and selling our natural gas. In such an event, we might have to shut in our wells while awaiting a pipeline connection or additional capacity, which would adversely affect our results of operations. Even when available, the ultimate costs of gathering and transportation systems may prevent some of our properties from being economically viable.

A portion of our natural gas production may be interrupted, or shut in, from time to time for numerous reasons, including weather conditions, accidents, loss of pipeline or gathering system access, field labor issues or strikes, or we might voluntarily curtail production in response to market conditions. If a substantial amount of our production is interrupted at the same time, it could materially adversely affect our cash flow.

Drilling, completions, workover and hydraulic fracturing operations are operationally complex activities which present certain risks that could adversely affect our business, financial condition or results of operations.

In our drilling operations, from time to time we experience certain issues and encounter risks, including, for example, mechanical and instrument or tool failures; drilling difficulties associated with drilling in swelling clay or shales and unconsolidated formation; wellbore instability and other geological hazards; loss of well control and associated hydrocarbon release and/or natural gas clouds; loss of drilling fluids circulation; surface spills of various drilling or well fluids; subsurface collision with existing wells; proximity of adjacent water wells or aquifers; inability to establish drilling fluid circulation; loss or compromise of drill pipe or casing integrity; surface pumping operations and associated pressure and hydrocarbon hazards; stuck and lost-in-hole tools, drill pipe or casing; large drilling equipment and machinery including electrical hazards; insufficient cementing of casing causing unwanted casing pressure or fluid migration; surface overpressure events from large machinery (horsepower), equipment or well pressure; fines and violations related to relevant laws and regulations; fires and explosions; personnel safety hazards such as working at heights, driving or equipment operation, energy isolation, excavation and trenching and more; structural damage and collapse to large equipment and machinery; major damage or malfunction to key equipment or processes; in certain instances, close proximity of operations to residences and/or communities; among other typical shale basin drilling challenges and risks.

In our hydraulic fracturing, workover and completions activities, from time to time we experience certain issues and encounter risks, including, for example, mechanical and instrument or tool failures; loss of well control and associated hydrocarbon release and/or natural gas clouds; well kick or flowback during completion or fracturing operations; lost or stuck in hole wireline, coiled tubing or workover strings and tools; loss or compromise of workover string, tubing or casing integrity; large completions, wireline, coiled tubing and workover rig equipment and machinery including electrical hazards; insufficient cementing of casing causing unwanted casing pressure or fluid migration while fracturing or thereafter; proximity of adjacent water wells or aquifers and adjacent producing wells; surface spills of various fracturing, freshwater or well fluids or chemicals; surface pumping and flowback operations and associated pressure and hydrocarbon hazards; surface overpressure events from large machinery (horsepower), equipment or well pressure; fines and violations related to relevant laws and regulations; fires and explosions; personnel safety hazards such as working at heights, driving or equipment operation, energy isolation, excavation and trenching and more; structural damage and collapse to large equipment and machinery; major damage or malfunction to key equipment or processes; in certain instances, close proximity of operations to residences and/or communities; among other typical fracturing, workover and completion challenges and risks.

Our industry requires us to navigate many uncertainties that could adversely affect our financial condition and results of operations.

Our financial condition and results of operations depend on the success of the development of our assets, which are subject to numerous risks beyond our control, including the risk that development will not result in commercially viable production or uneconomic results or that various characteristics of the drilling process or the well will cause us to abandon the well prior to fully producing commercially viable quantities.

Our actual development cost for a well could significantly exceed planned “authorization for expenditure” levels. Further, many factors may curtail, disrupt, delay or cancel our scheduled drilling projects and ongoing operations, including the following:

• reductions or sustained declines in natural gas prices; and
• regulatory compliance, including limitations on wastewater disposal, discharge of greenhouse gases and hydraulic fracturing.

In addition, our assets are anticipated to be developed over several years, making them susceptible to uncertainties that could materially alter the occurrence or timing of their drilling, the scope, rate of progress and cost of our exploration and production activities. Our ability to drill and develop our assets depends on a number of factors, including the availability of equipment and capital, seasonal conditions, regulatory approvals, obtaining land access agreements for regulated operations, natural gas prices, costs and drilling results. Because of these uncertainties, we do not know if our properties will be drilled within our expected timeframe or at all or if we will be able to economically produce natural gas from these or any other potential drilling locations. As such, our actual drilling activities may be materially different from our current expectations, which could adversely affect our results of operations and financial condition.

Natural gas prices are volatile. A reduction or sustained decline in prices may adversely affect our business, financial condition or results of operations and our ability to meet our financial commitments or raise capital.

Our future growth is dependent on the continued economic importance of the natural gas development and production industry in Australia and global demand (as it relates to LNG trade). Any substantive and prolonged changes to the current economic importance of natural gas development and production industry in Australia would be likely to have an adverse effect on our business, financial condition and profits.

Prevailing natural gas prices heavily influence our potential revenue, profitability, access to capital, growth rate and value of our properties. Further, although we do not produce oil, to the extent oil prices rise considerably, the cost of services we incur may also increase. As a commodity, natural gas prices are subject to wide fluctuations in response to relatively minor changes in supply and demand. Historically, the natural gas market has been volatile. Our revenue, profitability and future growth are highly dependent on the prices we receive for our natural gas production, and the levels of our production, which depend on numerous factors beyond our control. These factors include, but are not limited to, the following:

• worldwide and regional economic conditions impacting the global supply of and demand for natural gas, including economic growth expectations, inflation and hostilities in Ukraine and the Middle East;
• the actions of OPEC, its members and other state-controlled oil companies relating to oil price and production controls;
• the level of global oil and natural gas exploration and production;
• the level of global oil and natural gas inventories;
• prevailing prices on local price indexes in the areas in which we operate and expectations about future commodity prices;
• extent of natural gas production associated with increased oil production;
• the proximity, capacity, cost and availability of gathering and transportation facilities;
• localized and global supply and demand fundamentals and transportation availability;
• weather conditions across the globe;
• technological advances affecting energy consumption;
• speculative trading in natural gas markets;
• end-user conservation trends;
• petrochemical, fertilizer, ethanol, transportation supply and demand balance;
• the price and availability of alternative fuels;
• domestic, local and foreign governmental regulation and taxes; and
• liquefied petroleum products supply and demand balances.

In particular, because of our higher operating costs than U.S. producers, our business model is dependent on the higher natural gas prices we receive from Asian and domestic Australian markets relative to U.S. prices. If commodity prices decrease or we experience widening of basis differentials, our cash flows and refinancing ability will be reduced. We may be unable to obtain needed capital or financing on commercially reasonable terms. Lower commodity prices may also reduce the amount of natural gas that we can produce economically. Additionally, a significant portion of our projects could become uneconomic and require us to abandon or postpone our planned drilling. As a result, a reduction or sustained decline in natural gas prices may materially and adversely affect our financial condition, results of operations, liquidity and our ability to finance capital expenditures.

We may not be able to manage our future growth effectively, which could make it difficult to execute our business strategy.

Our expected future growth could create a strain on the organizational, administrative and operational infrastructure. Our ability to manage our growth effectively will require us to continue to improve our operational, financial and management controls, as well as reporting systems and procedures. Our current team is small, and we will have to hire additional employees to achieve our expected future growth. Our business strategy will be difficult to execute, which may impact our ability to effectively attract employees. As we grow, any failure of our controls or interruption of our facilities or systems could have a negative impact on our business and financial operations. Our future development plan, including the potential development of pipelines, and an LNG export facility, will affect a broad range of business processes and functional areas. The time and resources required to implement these new extensions of our business are uncertain, and failure to complete these activities in a timely and efficient manner could adversely affect our operations. If we are unable to manage growth effectively, it may be difficult for us to execute our business strategy.

Our business plan contemplates the execution of midstream contracts with certain third parties in order to allow us to supply our own natural gas to the Northern Territory, the Australian East Coast, and/or for export out of Darwin. We cannot assure you that we will be successful in obtaining the commercial contracts necessary to facilitate direct delivery of our natural gas production on commercially reasonable terms, or at all.

We cannot assure you that we will succeed in any effort to establish midstream contracts that would allow us to supply our own natural gas for export out of Darwin or directly to the Australian East Coast. Even when the physical infrastructure exists to supply our own natural gas directly to Darwin and the Australian East Coast, our ability to utilize that infrastructure depends on whether we can successfully negotiate and enter into midstream contracts on commercially reasonable terms or at all. If we fail to enter into such contracts on commercially reasonable terms or at all or are otherwise subject to capacity constraints, it could have a material adverse effect on our business, financial condition, results of operations and cash flows.

Construction of midstream projects subjects us to risks of construction delays, cost overruns, limitations on our growth and negative effects on our financial condition, results of operations, cash flows and liquidity.

The second and third phases of our business require the construction of midstream projects, including pipelines to access the East Coast and our proposed NTLNG terminal, some of which may take a number of years before commercial operation. These projects are complex and subject to a number of factors beyond our control, including delays from third-party landowners, the permitting process, government and regulatory approval, compliance with laws, unavailability of materials, labor disruptions, environmental hazards, financing, accidents, weather and other factors. Any delay in the completion of these projects could have a material adverse effect on our financial condition, results of operations, cash flows and the ability to pay dividends on our common stock. The construction of these midstream facilities requires the expenditure of significant amounts of capital, which may exceed our estimated costs. Estimating the timing and expenditures related to these development projects is very complex and subject to variables that can significantly increase expected costs. Should the actual costs of these projects exceed our estimates, our liquidity and financial condition could be adversely affected. This level of development activity requires significant effort from our management and technical personnel and places additional requirements on our financial resources and internal financial controls. We may not have the ability to attract and/or retain the necessary number of personnel with the skills required to bring complicated projects to successful conclusions.

The construction of midstream projects also requires the support of third-party strategic partners, who may have differing goals and strategies. If our strategic partners do not cooperate in the construction of the midstream projects, we may be unable to market our future natural gas production.

If our assessments of the Beetaloo are materially inaccurate, it will have a fundamental impact on our business.

Our assessment of our property may be inherently inexact and may be inaccurate, including the following:

• the time it takes to bring the Beetaloo to commercial development phase;
• the amount of recoverable reserves;
• timing of development of takeaway capacity and access to other infrastructure, including LNG terminals, on an economically viable basis;
• geological complexity;
• applicable governmental rules and regulations;
• native title holders and traditional Aboriginal owners;
• estimates of operating costs;
• estimates of future development costs;
• estimates of the costs and timing of plugging and abandonment; and
• potential environmental and other liabilities.

Our assessments will not reveal all existing or potential problems, nor will they permit us to become familiar enough with the breadth of the territory we hold license to in order to assess fully their capabilities and deficiencies. We plan to undertake further development of our properties through the use of cash flow from existing production. Therefore, a material deviation in our assessments of these factors could result in less cash flow being available for such purposes than we presently anticipate, which could either delay future development operations (and delay the anticipated conversion of reserves into cash), or cause us to seek alternative sources to finance development activities.

Numerous uncertainties exist in estimating quantities of proved and possible reserves, and any such estimates may be inaccurate.

Reserve engineering is a process of estimating commercially recoverable amounts of petroleum that remain in known accumulations that cannot be measured in an exact way. The accuracy of any reserve estimate depends on the quality of available data, the interpretation of such data and price and cost assumptions made by reserve engineers. In estimating probable reserves, it should be noted that those reserve estimates inherently involve greater risk and uncertainty than estimates of proved reserves. Any estimates of proved and probable reserves presented in this report have not been adjusted for risk due to their uncertainty of recovery and are not comparable to measures of proved and probable reserves that we or any other company may provide. In addition, amounts of proved and probable reserves provided by us or any other company should not be summed into total amounts due to the aforementioned uncertainties.

We are dependent on certain members of our management and technical team.

Investors in our common stock must rely upon the ability, expertise, judgment and discretion of our management and the success of our technical team in developing our future natural gas reserves. Our performance and success are dependent, in part, upon key members of our management and technical team, and their loss or departure could be detrimental to our future success. In making a decision to invest in our common stock, you must be willing to rely to a significant extent on our management’s discretion and judgment. There can be no assurance that our senior management will remain in place. The loss of any of our management and technical team members could have a material adverse effect on our results of operations and financial condition, as well as on the market price of our common stock.

We have limited control over properties and investments operated by others or through joint ventures.

Certain of our properties are operated by other companies and may involve third-party working interest owners. We have limited influence and control over the operation or future development of such properties and investments, including compliance with environmental, health and safety regulations or the amount and timing of required future capital expenditures. In addition, we conduct certain of our operations through joint ventures in which we may share control with third parties, and the other joint venture participants may have interests or goals that are inconsistent with those of the joint venture or us. These limitations and our dependence on such third parties could result in unexpected future costs or liabilities and unplanned changes in operations or future development, which could adversely affect our financial condition and results of operations.

Our financial performance is subject to our counterparties’ or joint venture partners’ performance of their obligations under the relevant contracts, including the joint venture agreements. If one of our counterparties or joint venture partners fails to perform its contractual obligations, it may result in loss of earnings, termination of other related contracts, disputes and/or litigation that could impact our financial performance.

Currently, we are not the operator of EP 161, which is operated by Santos. As we carry out our exploration and development programs, we may enter into arrangements with respect to existing or future properties that result in a greater proportion of our properties being operated by others. As a result, we may have limited ability to exercise influence over the operations of the properties operated by our partners. Dependence on the operator could prevent us from realizing our target returns for those properties. Further, it may be difficult for us to pursue one of our key business strategies of minimizing the cycle time between discovery and initial production with respect to properties for which we do not operate. The success and timing of exploration and development activities operated by our partners will depend on a number of factors that will be largely outside of our control, including:

• the timing and amount of capital expenditures;
• the operator’s expertise and financial resources;
• approval of other participants in drilling wells;
• selection of technology; and
• the rate of production of reserves, if any.

This limited ability to exercise control over the operations of some of our properties may cause a material adverse effect on our results of operations and financial condition.

The inability of one or more third parties who contract with us to meet their obligations to us may adversely affect our financial results.

We may be liable for certain costs if third parties who contract with us or with the operators of our permit areas are unable to meet their commitments under such agreements. We are currently exposed to credit risk through joint interest receivables from our joint venture partners. If any of our partners in which we hold interests are unable to fund their share of the exploration or development expenses, we may be liable for such costs. This could result in such party being in default, which in turn would require the Company and its non‑defaulting block partners to pay their proportionate share of the defaulting party’s costs during the default period. Should a default not be cured, the Company could be required to pay its share of the defaulting party’s costs going forward. In addition, we and the operators of our permit areas contract with third parties to conduct drilling and related services on our development projects and exploration prospects. Such third parties may not perform the services they provide us on schedule or within budget. Furthermore, the drilling equipment, facilities and infrastructure owned and operated by such third parties are highly complex and subject to malfunction and breakdown. Any malfunctions or breakdowns may be outside our control and result in delays, which could be substantial. Any delays in our drilling campaign caused by equipment, facility or infrastructure malfunction or breakdown could materially increase our costs of drilling and cause an adverse effect on our business, financial position and results of operations. We are currently exposed to credit risk through receivables resulting from the sale of our natural gas and cash term deposits held with banks. The inability or failure of our significant customers or counterparties to meet their obligations to us or their insolvency or liquidation may adversely affect our financial results. The inability or failure of third parties we contract with to meet their obligations to us or their insolvency or liquidation may adversely affect our financial results. We are unable to predict sudden changes in creditworthiness or ability to perform. Even if we do accurately predict sudden changes, our ability to negate the risk may be limited and we could incur significant financial losses.

A majority of our assets and operations are located in the Beetaloo, making us vulnerable to risks associated with operating in one geographic area.

Our operations are geographically concentrated in the Northern Territory of Australia, and specifically the Beetaloo. As a result, we may be disproportionately exposed to the impact of regional supply and demand factors in the Beetaloo caused by significant governmental regulation, curtailment of production or interruption of the processing or transportation of natural gas produced from wells in this area. In addition, the effect of fluctuations on supply and demand may become more pronounced within a specific geographic natural gas producing area such as the Beetaloo, which may cause these conditions to occur with greater frequency or magnify the effects of these conditions. Due to the concentrated nature of our operations, we could experience any of the same conditions at the same time, resulting in a relatively greater impact on our revenue than they might have on other companies that have more geographically diverse operations.

We may be unable to make accretive acquisitions or successfully integrate acquired businesses or assets, and any inability to do so may disrupt our business and hinder our growth potential.

Our ability to grow may in the future depend in part on our ability to make acquisitions that result in an increase in cash available for distribution. There is intense competition for acquisition opportunities in our industry, and we may not be able to identify attractive acquisition opportunities. Even if we do identify attractive acquisition opportunities, we may not be able to complete the acquisition, do so on commercially acceptable terms or obtain sufficient financing to do so. Competition for acquisitions may increase the cost of, or cause us to refrain from, completing acquisitions. The success of any completed acquisition will depend on our ability to integrate effectively the acquired business into our existing operations. The process of integrating acquired businesses may involve unforeseen difficulties and may require a disproportionate amount of our managerial and financial resources. Our failure to achieve consolidation savings, to successfully integrate the acquired businesses and assets into our existing operations or to minimize any unforeseen operational difficulties could have a material adverse effect on our financial condition and results of operations.

Our business is subject to operating hazards that could result in substantial losses or liabilities for which we may not have adequate insurance coverage.

Natural gas operations are subject to many risks, including well blowouts, craterings, explosions, uncontrollable flows of natural gas or well fluids, fires, pipe, casing or cement failures, abnormal pressure, pipeline leaks, ruptures or spills, vandalism, pollution, releases of toxic gases, adverse weather conditions or natural disasters and other environmental hazards and risks. If any of these hazards occur, we could sustain substantial losses as a result of:

• injury or loss of life;
• severe damage to or destruction of property, natural resources and equipment;
• pollution or other environmental damage;
• investigatory, monitoring, and cleanup responsibilities;
• regulatory investigations and penalties or lawsuits;
• loss of, or delay in, revenue;
• suspension or impairment of operations; and
• repairs to resume operations.

We maintain insurance against some, but not all, potential losses or liabilities arising from our operations in accordance with what we believe are customary industry practices and in amounts and at costs that we believe to be prudent and commercially practicable. Our insurance includes deductibles that must be met prior to recovery, as well as sub-limits and/or self-insurance. Additionally, our insurance is subject to exclusions and limitations. Our insurance does not cover every potential risk associated with our operations, including the potential loss of significant revenues. We can provide no assurance that our coverage will adequately protect us against liability from all potential consequences, damages and losses.

We maintain insurance coverage that is considered appropriate for a company of our size, subject to policy terms and conditions. This includes insurance coverage related to general and product liability, property, directors and officers, workers compensation, cyber, operator’s extra expenses for control of well, seepage and pollution, cleanup and contamination, evacuation expenses and making the well safe.

We may elect not to obtain insurance if we believe that the cost of available insurance is excessive relative to the risks presented. Some forms of insurance may become unavailable in the future or unavailable on terms that we believe are economically acceptable. No assurance can be given that we will be able to maintain insurance in the future at rates that we consider reasonable, and we may elect to maintain minimal or no insurance coverage. If we incur substantial liability from a significant event and the damages are not covered by insurance or are in excess of policy limits, then we would have lower revenues and funds available to us for our operations, that could, in turn, have a material adverse effect on our business, financial condition and results of operations.

Additionally, we will rely to a large extent on transportation infrastructure owned and operated by third parties and damage to, or destruction of, third-party infrastructure will affect our ability to process, transport and sell our production.

We are subject to numerous risks inherent to the exploration and production of natural gas.

Natural gas exploration and production activities involve many risks that a combination of experience, knowledge and careful evaluation may not be able to overcome. Our future success will depend on the success of our exploration and production activities and on the future existence of the infrastructure that will allow us to take advantage of our findings. Additionally, our natural gas properties are located in an area without significant existing infrastructure, which generally increases the capital and operating costs, technical challenges and risks associated with natural gas exploration and production activities. As a result, our natural gas exploration and production activities are subject to numerous risks, including the risk that drilling will not result in commercially viable natural gas production. Our decisions to purchase, explore, develop or otherwise exploit properties will depend in part on the evaluation of seismic data through geophysical and geological analyses, production data and engineering studies, the results of which are often inconclusive or subject to varying interpretations.

Furthermore, the marketability of expected natural gas production from our property will also be affected by numerous factors. These factors include, but are not limited to, market fluctuations of prices, proximity, capacity and availability of pipelines, the availability of processing facilities, equipment availability and government regulations (including, without limitation, regulations relating to prices, taxes, royalties, allowable production, importing and exporting of natural gas, environmental protection and climate change). The effect of these factors, individually or jointly, may result in us not receiving an adequate return on invested capital.

In the event that our drilling programs are developed and become operational, they may not produce natural gas in commercial quantities or at the costs anticipated, and our projects may cease production, in part or entirely, in certain circumstances. Drilling programs may become uneconomic as a result of an increase in operating costs to produce natural gas. Our actual operating costs may differ materially from our current estimates. Moreover, it is possible that other developments, such as increasingly strict environmental, health and safety laws and regulations and enforcement policies thereunder and claims for damages to property or persons resulting from our operations, could result in substantial costs and liabilities, delays, an inability to complete our drilling programs or the abandonment of such drilling programs, which could cause a material adverse effect on our results of operations and financial condition.

Our identified drilling locations are scheduled out over several years, making them susceptible to uncertainties that could materially alter the occurrence or timing of their drilling.

Our management team has identified and scheduled drilling locations on our acreage over a multi-year period. Our ability to drill and develop these locations depends on a number of factors, including the availability of equipment and capital, seasonal conditions, regulatory approvals, natural gas prices, costs and drilling results. The final determination on whether to drill any of these drilling locations will be dependent upon the factors described above as well as, to some degree, the results of our drilling activities with respect to our appraisal wells. Because of these uncertainties, we do not know if the drilling locations we have identified will be drilled within our expected timeframe or at all. As such, our actual drilling activities may be materially different from our current expectations, which could adversely affect our results of operations and financial condition.

The development schedule of natural gas projects, including the availability and cost of drilling rigs, equipment, supplies, personnel and natural gas field services, is subject to delays and cost overruns.

Historically, some natural gas projects have experienced delays and capital cost increases and overruns due to, among other factors, the unavailability or high cost of drilling rigs and other essential equipment, supplies, personnel and natural gas field services. The cost to develop our projects has not been fixed and remains dependent upon a number of factors, including the completion of detailed cost estimates and final engineering, contracting and procurement costs. Our construction and operation schedules may not proceed as planned and there may be delays or cost overruns. Any delays may increase the costs of the projects, requiring additional capital, and such capital may not be available in a timely and cost-effective fashion.

Part of our business strategy involves using some of the latest available horizontal drilling and completion techniques, which involve risks and uncertainties in their application.

Difficulties that we face while completing our wells include:

• the ability to fracture stimulate the planned number of stages with the planned amount of proppant;
• the ability to run tools through the entire length of the wellbore during completion operations; and
• the ability to successfully clean out the wellbore after completion of the final fracture stimulation stage.

In addition, certain of the new techniques we are adopting may cause irregularities or interruptions in production. If our development and production results are less than anticipated, the return on our investment for a particular well may not be as attractive as we anticipated, and its value could decline in the future.

We also may be subject to additional costs or shortages of equipment and labor because of the necessity of importing certain equipment or hiring talent from the United States. The unavailability or high cost of drilling rigs, completion crews, equipment, supplies, personnel and oilfield services could adversely affect our ability to execute our development plans within our budget and on a timely basis.

Shale gas completions require significant amounts of water that is subject to delays in regulatory approval from certain aquifers and the cost of utilization of aquifer water may increase over time.

The demand for drilling rigs, completion crews, pipe and other equipment and supplies, including sand and other proppant used in hydraulic fracturing operations and acid used for stimulation can fluctuate significantly, often in correlation with commodity prices or drilling activity in our area of operation and in other shale basins, causing periodic shortages of supplies and needed personnel and rapid increases in costs. Increased drilling activity could materially increase the demand for and prices of these goods and services, and we could encounter rising costs and delays in or an inability to secure the personnel, equipment, power, services, resources and facilities access necessary for us to conduct our drilling and development activities, which could result in production volumes being below our forecasted volumes. In addition, any such negative effect on production volumes, or significant increases in costs could have a material adverse effect on our future cash flow and profitability.

Our recurring losses from operations, negative cash flows and substantial cumulative net losses raise substantial doubt about our ability to continue as a going concern.

In Note 1 titled “Business and Basis of Preparation” of our audited consolidated financial statements for fiscal years 2025 and 2026 included elsewhere in this report, we disclose that there is substantial doubt about our ability to continue as a going concern. In addition, our independent registered public accounting firm included an explanatory paragraph in its report on our consolidated financial statements for fiscal years 2025 and 2026, which stated that there are factors that raise substantial doubt on our ability to continue as a going concern. We have incurred significant operating losses and negative cash flows from operations and expect to continue incurring increasing losses for the foreseeable future as we further our development program. Further, we had accumulated a deficit of $167.3 million as of June 30, 2025 and $193.4 million as of June 30, 2026. These conditions raise substantial doubt about our ability to continue as a going concern. Our consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.

Our ability to become a profitable operating company is dependent upon our ability to generate revenue and obtain financing adequate to fulfill our development and commercialization activities and achieving a level of revenue adequate to support our cost structure. We have plans to obtain additional resources to fund our currently planned operations and expenditures through additional debt and equity financing, however, there is no guarantee we will obtain financing at all or on commercially acceptable terms. We may not continue as a going concern if we do not raise additional capital. We believe that the proceeds raised from the capital raise in April 2026 and the undrawn portion of the SPCF debt facility provide us with the funds necessary to continue as a going concern over the next 12 months. Our plans are substantially dependent upon the success of commercial production in the Beetaloo, which is still in the early stages of development, and are dependent upon, among other things, the success of our drilling program and infrastructure development in the Beetaloo. If we are unable to obtain sufficient funding, our financial condition and results of operations will be materially and adversely affected, and we may be unable to continue as a going concern. Future financial statements may disclose substantial doubt about our ability to continue as a going concern. If we seek additional financing to fund our business activities in the future and there remains substantial doubt about our ability to continue as a going concern, investors or other financing sources may be unwilling to provide additional funding to us on commercially reasonable terms or at all.

Our long-term business plan contemplates the development of an additional LNG export terminal on the northern coast of Australia. Our ability to develop such a facility is dependent on our ability to attract a third-party partner as well as securing the necessary permits.

Our ability to commence construction of the NTLNG project on schedule is dependent on a number of factors outside of our control, including the willingness of potential third-party partners to commit to the project. Although we have entered into memoranda of understanding with subsidiaries of each of bp and Shell with respect to long-term contracts for the purchase of a total of 4.4 MTPA from the NTLNG project, these memoranda of understanding are not binding obligations of bp or Shell and either may decide not to pursue our project.

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

Concerns over global economic conditions, stock market volatility, energy costs, geopolitical issues, supply chain issues, changing regulatory environment and tariffs and trade policies, inflation and elevated interest rates, the availability and cost of credit, and slowing of economic growth in the United States and fears of a recession have contributed and may continue to contribute to economic uncertainty and diminished expectations for the global economy.

As a result of inflation, we experienced supply chain constraints and inflationary pressure on our cost structure throughout fiscal year 2026. Principally, commodity costs for steel and chemicals required for drilling, higher transportation and fuel costs and annual wage increases have increased our operating costs for fiscal year 2026 compared to fiscal year 2025. We cannot predict the future inflation rate but to the extent inflation remains elevated and supply chain constraints remain, we may experience cost increases in our operations, including costs for drill rigs, workover rigs, hydraulic fracturing fleets, tubulars and other well equipment, as well as increased labor costs. Some supply chain constraints and inflationary pressures could persist into fiscal year 2027 but are expected to plateau; however, we cannot accurately predict future supply chain constraints and inflation. If we are unable to manage our supply chain, our ability to procure materials and equipment in a timely and cost-effective manner, if at all, may be negatively impacted, which could materially adversely impact our results of operations and financial condition.

Similarly, we cannot predict the impact that high market volatility and instability in the banking sector could have on economic activity and our business in particular. The failure of banks and financial institutions and measures taken, or not taken, by governments, businesses and other organizations in response to these events could adversely impact our business, financial conditions and results of operations.

In addition, continued hostilities between Russia and Ukraine, the conflict between Iran and the United States, the conflict between Israel and Hamas, other hostilities in the Middle East, and the occurrence or threat of terrorist attacks in Australia or other countries could adversely affect the economies of Australia and other countries. The ongoing conflicts in Ukraine, Iran and Israel could continue to have repercussions globally by continuing to cause uncertainty, not only in the natural gas markets, but also in the capital markets. Such uncertainty could result in stock price volatility and supply chain disruptions, as well as higher natural gas prices which could potentially result in increased inflation worldwide and could negatively impact demand for natural gas, NGLs, oil and electricity.

Our business, results of operations and financial condition may be adversely affected by uncertainty and changes in the U.S. regulatory environment and trade policies, including tariffs, trade agreements or other trade restrictions imposed by the U.S. or other governments. Tariffs or other trade restrictions may lead to continuing uncertainty and volatility in U.S. and global financial and economic conditions and commodity markets, declining consumer confidence, inflation and diminished expectations for the economy, which could impact the demand for and price of oil and natural gas, increase the price of supplies and raw materials that we rely on to conduct our business, and could impact interest rates. Changing regulatory environment and trade and tariffs policies could ultimately impact our results of operations and financial condition.

Concerns about global economic growth can result in a significant adverse impact on global financial markets and commodity prices. In addition, any financial crisis may cause us to face limitations on our ability to access the debt and equity capital markets and complete asset purchases or sales.

Further, if there is a financial crisis or the economic climate in Australia or abroad deteriorates, worldwide demand for hydrocarbon-based products could materially decrease, which could impact the price at which natural gas from our properties is sold, affect the ability of vendors, suppliers and service providers associated with our properties to continue operations and ultimately materially adversely impact our results of operations, financial condition and ability to pay dividends on our common stock.

Events outside of our control, including an epidemic or outbreak of an infectious disease, terrorism, geopolitical instability, and security threats, could have a material adverse effect on our business, liquidity, financial condition, results of operations, and/or cash flows.

We face risks related to pandemics, epidemics, outbreaks or other public health events, or the threat thereof, that are outside of our control and could significantly disrupt our business and operational plans and adversely affect our liquidity, financial condition, results of operations, cash flows and ability to pay dividends on our common stock.

The nature, scale and scope of the above-described events, combined with the uncertain duration and extent of governmental actions, prevent us from identifying all potential risks to our business. We believe that the known and potential impacts of pandemic-related events include, but are not limited to, the following:

• disruption in the demand for natural gas, NGLs and oil and other petroleum products;
• intentional project delays until commodity prices stabilize;
• a potential future downgrade of our credit rating and potentially higher borrowing costs in the future;
• a need to preserve liquidity, which could result in reductions, delays or changes in our capital expenditures;
• supply chain and shipping lane disruptions, resulting in shortages of, and increased pricing pressures on, among other things, equipment, services and labor;
• liabilities resulting from operational delays due to decreased productivity resulting from stay-at-home orders affecting our workforce or facility closures;
• future asset impairments, including impairment of our natural gas properties and other property and equipment; and
• infections and quarantining of our employees and the personnel of vendors, suppliers and other third parties.

A terrorist attack or armed conflict targeting our systems or natural gas infrastructure generally could materially adversely impact our operations.

Growing geopolitical instability and armed conflicts (including the armed conflict between Russia and Ukraine, Iran and the United States and between Israel and Hamas as well as other hostilities in the Middle East) have resulted in energy infrastructure becoming a more prominent target of attack by terrorists and conflicting countries. Natural gas, NGLs and oil related facilities, including those operated by us or our service providers, could be direct targets of physical or cyber-attacks, and, if infrastructure integral to our operations is destroyed or damaged, we may experience a significant disruption in our operations. Any such disruption could materially adversely affect our financial condition, results of operations and cash flows. Costs for insurance and other security may increase as a result of increased threats, and certain insurance coverage may become more difficult to obtain, if available at all.

Our business could be negatively affected by security threats and disruptions, including electronic, cybersecurity or physical security threats and other disruptions.

We rely on computer systems, hardware, software, technology infrastructure and online sites and networks for both internal and external operations that are critical to our business (collectively, “IT Systems”). We own and manage some of these IT Systems but also rely on third parties for a range of IT Systems and related products and services. Our business faces numerous and evolving security threats, including cybersecurity risks that threaten the confidentiality, integrity and availability of our IT Systems and information that we collect, maintain and process, including personal, confidential and other types of proprietary or sensitive information (collectively, “Confidential Information”); threats to the security of our facilities and infrastructure or third-party facilities and infrastructure, such as processing plants and pipelines; and threats from terrorist acts, civil unrest and similar acts. The potential for such security threats has subjected our operations to increased risks that could have a material adverse effect on our business. In particular, our implementation of various procedures and controls to monitor and mitigate security threats and to increase security for our information, facilities and infrastructure may result in increased capital and operating costs. Moreover, there can be no assurance that such procedures and controls will be sufficient to prevent security threats, incidents or disruptions from occurring. Security incidents could lead to losses of Confidential Information, critical infrastructure or capabilities essential to our operations, or otherwise impact the availability, integrity or confidentiality of our IT Systems and Confidential Information and could have a material adverse effect on our reputation, financial position, results of operations and cash flows.

There can be no assurance that our efforts to secure our IT Systems will be effective in protecting such IT Systems, facilities, infrastructure and Confidential Information, or that future attempted cybersecurity attacks, incidents, or disruptions would not be successful or damaging. Cybersecurity attacks and risks in particular are becoming more varied, and include threats from diverse vectors such as social engineering/phishing, malware (including ransomware), malfeasance by insiders, human or technological error, as a result of malicious software or malicious code embedded in open-source software, misconfigurations, bugs or other vulnerabilities in commercial software that are integrated into our (or our third party’s) IT Systems. The threat landscape is constantly evolving as threat actors become increasingly sophisticated in using techniques and tools – including artificial intelligence and other emerging technologies – that circumvent security controls, evade detection and remove forensic evidence. As a result, we may be unable to detect, investigate, remediate or recover from future attacks or incidents, or to avoid a material adverse impact to our IT Systems, Confidential Information or business. We and certain of our third-party vendors and suppliers have in the past experienced cyberattacks and other incidents, and we expect such incidents to continue to varying degrees. While to date no incidents have had a material impact on our operations, we cannot guarantee that material incidents will not occur in the future.

Any adverse impact on the availability, integrity or confidentiality of our IT Systems or Confidential Information, including any attempts to gain unauthorized access to information and systems and other security incidents or breaches, could lead to disruptions in critical systems, unauthorized release of information and corruption of data. They could also damage our reputation, lead to legal claims or proceedings, regulatory investigations and enforcement actions, significant costs from remedial actions, loss of business or potential liability. We cannot guarantee that any costs and liabilities incurred in relation to an attack or incident will be covered by our existing insurance policies or that applicable insurance will be available to us in the future on economically reasonable terms or at all.

We are incorporating artificial intelligence technologies into our processes and these technologies may present business, operational, compliance, cybersecurity, and reputational risks.

Our business is increasingly evaluating the use of and utilizing artificial intelligence (“AI”), machine learning and automation to improve our internal processes and support operational and strategic decisions. The development, deployment and use of these technologies, combined with an evolving and uncertain regulatory environment, may result in new or heightened governmental or regulatory scrutiny, litigation, confidentiality or security risks, reputational harm, liability or other adverse consequences to our business operations, any of which could adversely affect our business, financial condition and results of operations. The use of AI tools can lead to unintended consequences, including the unauthorized use or disclosure of confidential and proprietary information, or the generation of content or outputs that appear correct but are factually inaccurate, misleading, or otherwise flawed. Reliance on such outputs could expose us to risks related to inaccuracies or errors in the output of such technologies. We are in the process of establishing an internal AI strategy and governance including evaluating the costs, benefits, risks and opportunities associated with the use of any AI tools in our business and recommending mitigation measures, as well as developing and implementing an AI use policy across the Company. However, these governance measures may not be effective in all cases, and it is not possible to predict or prevent all of the risks related to the use of AI, machine learning, and automated decision-making technologies. In addition, future changes in laws or developments in the regulatory frameworks governing the use of such technologies and in related stakeholder expectations could restrict or limit our use of AI, increase our compliance costs, or subject us to liability, any of which could adversely affect our ability to develop and use such technologies.

Loss of or compromise to our information and computer systems could adversely affect our business.

We are heavily dependent on our IT Systems, including computer-based programs, and those of third parties, including our well operations information, seismic data, electronic data processing and accounting data. If any of such systems or programs were to experience service interruptions, fail or create erroneous information in our hardware or software network infrastructure, possible consequences include our loss of communication links, inability to find, produce, process and sell natural gas and inability to automatically process commercial transactions or engage in similar automated or computerized business activities. Any such consequence could have a material adverse effect on our business.

We may be involved in legal proceedings that could result in substantial liabilities.

Like many energy companies, in the ordinary course of our business, we are from time to time involved in various disputes and disagreements that may lead to legal and other proceedings, such as title, royalty or contractual disputes, regulatory compliance matters, land access disputes, appeals and judicial reviews of regulatory approvals, personal injury or property damage matters. Such legal proceedings are inherently uncertain, and their results cannot be predicted. Regardless of the outcome, such proceedings could have an adverse impact on us because of legal costs, diversion of management and other personnel and other factors. In addition, it is possible that a resolution of one or more such proceedings could result in liability, penalties or sanctions, as well as judgments, consent decrees or orders requiring a change in our business practices, which could materially and adversely affect our business, prospects, financial condition, results of operations, cash flows and ability to pay dividends on our common stock. Accruals for such liability, penalties or sanctions may be insufficient, and judgments and estimates to determine accruals or range of losses related to legal and other proceedings could materially change from one period to the next.

We are subject to risks related to corporate social responsibility, including the risk that our expectations or estimates regarding environmental, social and governance matters may not be achieved or may be incorrect.

Our business, as well as those of other companies, faces public scrutiny related to sustainability and ESG activities, which are increasingly considered to contribute to the long-term sustainability of a company’s performance.

We risk damage to our brand and reputation if we fail, or are perceived to fail, to act responsibly in a number of areas, such as environmental stewardship and corporate governance and transparency. Adverse incidents with respect to sustainability and ESG activities could impact the value of our brand, the cost of our operations and relationships with investors, all of which could adversely affect our business and results of operations. For example, we have been in the past, and may in the future be, subject to claims of “greenwashing” (e.g., if our carbon footprint is alleged to be greater than what we claim, or if our ESG claims (including our claims in relation to our goals in respect of net zero equity Scope 1 and 2 emissions) turn out to be false or misleading). Our expectations and estimates regarding ESG matters, including the potential environmental impact of our development and initiatives, may not be achieved or may ultimately prove to be incorrect or out of keeping with evolving best practices, which may lead to additional claims or liability. The law in relation to false and misleading claims about ESG matters and statements about “net zero” emissions goals is evolving, and there continues to be risk that statements we have made could be deemed to be in breach of the Australian Consumer Law and other similar legislation in Australia or other jurisdictions. Breaches of these laws can result in significant financial penalties and other enforcement action.

Some of our sustainability and ESG efforts may ultimately rely on the right to claim certain emissions offsets or other environmental attributes or to package such attributes with the natural gas we produce. This may be affected by evolving approaches to these matters, complex calculations or commercial agreements, and any disputes or ambiguities regarding such environmental attributes may negatively affect perceptions of our operations and products, subject us to litigation or stakeholder activism, require us to incur additional costs to procure replacement attributes, or otherwise adversely impact our operations.

We are also subject to evolving expectations on ESG matters from various stakeholders, including regulators, investors, customers, and business partners. Further, in response to the evolving regulatory environment and investor expectations, or due to our acquisitions of other companies or assets, we may, periodically, make adjustments to our environmental targets or goals. See “Attention to sustainability and ESG matters and environmental conservation measures may adversely impact our business.”

Risks Related to Environmental, Legal Compliance and Regulatory Matters

We are subject to complex federal, local and other laws and regulations that could adversely affect the cost, manner or feasibility of conducting our operations or expose us to significant liabilities.

Exploration and production activities in the oil and natural gas industry within Australia are subject to extensive local, state, federal and international laws and regulations that are subject to change from time to time. We may be required to make material expenditures to comply with governmental laws and regulations, particularly in respect of the following matters:

• approvals for drilling operations and other regulated activities;
• land access;
• royalties and royalty increases;
• drilling development and decommissioning bonds;
• cost recovery for regulatory approvals;
• securities and orphan well levies;
• reports concerning operations;
• the spacing of wells;
• tenure, landholders, native title holders and traditional Aboriginal owners;
• greenhouse gas emission targets and offset requirements;
• water extraction and disposal;
• environmental assessment;
• remediation or investigation activities for environmental purposes;
• Australian domestic gas reservation policy; and
• taxation.

Under these and other laws and regulations, we could be liable for personal injuries, property damage and other types of damages, penalties, and costs. Accordingly, non-compliance may impact our ability to commercialize or retain our assets, which may in turn impact operational and financial performance. Failure to comply with these laws and regulations may also result in the suspension or termination of our operations, loss of permits and subject us to administrative, civil and criminal penalties. Moreover, these laws and regulations could change in ways that could substantially increase our costs. Any such liabilities, penalties, suspensions, or terminations or regulatory changes could have a material adverse effect on our financial condition and results of operations.

Our business is affected by government policy, which in turn may be influenced by international policies and laws. There is no guarantee that the current policy of the Australian Federal Government for the investment and development of Australia’s natural gas resources will not change in the future. In particular, there is a risk that the Australian Federal Government could shift its domestic or international policy. International policy developments have the potential to have an indirect impact on our operations, given that domestic policy makers might consider those developments in formulating and in setting the direction of local policy. For example, in May 2021, the International Energy Agency released a report in relation to its recommendations for a pathway to achieve global net zero emissions by 2050, which includes a key recommendation that no new oil and natural gas projects should be developed. It is unknown what impact the report might have, if any, on domestic policy development for natural gas. A shift in energy policy announced and adopted by the NT Government in relation to natural gas or the development of the Beetaloo would pose a similar risk. The NT Government had previously imposed a moratorium on the operations in the Beetaloo, which ended in 2018 following a scientific inquiry and the implementation of certain recommendations.

Shifts in government policy could have varying degrees of impact on our operations and profitability. These impacts could range from loss or reduction in industry incentives, preventing infrastructure development to temporary or permanent moratoriums on future natural gas development in specific areas or across the Beetaloo.

We must comply with relevant laws and regulations in each jurisdiction in which we operate as it applies to the environment, tenure, land access, landholders, native title holders and traditional Aboriginal owners. Non-compliance with these laws and regulations and any special license conditions could result in the suspension of operations, loss of permits or significant financial penalties. Non-compliance may impact our ability to commercialize or retain our assets, which may in turn impact our operational and financial performance.

Changes to these requirements (including, for example, new requirements relating to climate change, environmental protection and energy policy) may restrict or affect our right or ability to conduct our activities.

Our exploration of the Beetaloo is dependent upon the maintenance (including renewal) of our permits by the relevant authorities. Maintenance of the permits is dependent on, among other things, meeting the permit conditions imposed by the relevant authorities including compliance with work program and expenditure requirements. No assurance can be given that such title and access rights are not subject to unregistered, undetected or other claims or interests which could be materially adverse to our interests in the Beetaloo. Further titles or access rights may be disputed, which could result in costly litigation or disruption of the Company’s operations.

Our exploration and production operations are subject to various types of federal, state, territorial and local laws and regulations, and may be restricted or subject to conditions in relation to certain environmental features (such as watercourses or sites of conservation significance). Applicable law regulates the location of wells; the method of drilling, well construction, well stimulation, hydraulic fracturing and casing design; water withdrawal and procurement from designated aquifers for well stimulation purposes; well production; spill prevention plans; the use, transportation, storage and disposal of water and other fluids and materials, including solid and hazardous wastes, incidental to natural gas and oil operations; surface usage and the reclamation of properties upon which wells or other facilities have been located; the plugging and abandoning of wells; ongoing monitoring of wells, the calculation, reporting and disbursement of royalties and taxes; and the gathering of production in certain circumstances.

Our production operations are subject to the discovery of commercially exploitable petroleum and the discretion of the Minister for Mining and Energy for the NT Government to grant a production license. Specifically, we will only be entitled to apply for a production license once a commercially exploitable petroleum discovery is made. Further, the Minister may grant the production license subject to such conditions as the Minister determines to be appropriate at any time. Further the Minister may direct the holder of a production license to maintain, increase or reduce the rate of recovery of petroleum from the area which could impact profitability. The grant of any future production license to the Company over areas that are subject to native title rights and interests or are Aboriginal land will require engagement with the relevant native title holders and land councils in accordance with the Native Title Act 1993 (Cth) and the Aboriginal Land Rights (Northern Territory) Act 1976 (Cth) (ALRA) as relevant. Any delays or costs in engaging with the relevant native title holders in negotiating new arrangements in respect of a production license may adversely impact the Company’s ability to carry out petroleum extraction activities within the affected areas.

Our operations are also subject to the Petroleum Act 1984 (NT), which, among other matters, allows for the unitization of a petroleum pool that extends beyond a license area, but which is desirable for efficiency and avoiding wasteful and harmful development and practices.

Environmental and occupational health and safety laws and regulations govern discharges of substances into the air, ground and water; the management and disposal of hazardous substances and wastes; the clean-up of contaminated sites; groundwater quality and availability; plant and wildlife protection; locations available for drilling; environmental impact studies and assessments required for permitting; restoration of drilling properties upon completion of drilling activities; and work practices related to employee health and safety.

To conduct our operations in compliance with these laws and regulations, we must obtain and maintain numerous permits, approvals and certificates from various federal, state and local governmental authorities. Complying with the laws, regulations and other legal requirements applicable to our business and any delays in obtaining related authorizations may affect the costs and timing of developing our natural gas resources. These requirements could also subject us to claims for damages arising from personal injuries, property damage, penalties, costs and other losses. In addition, our costs of compliance may increase if existing laws and regulations are revised or reinterpreted, or if new laws and regulations become applicable to our operations. Such costs could materially adversely affect our results of operations, cash flows and financial position. Our failure to comply with the laws, regulations and other legal requirements applicable to our business, even as a result of factors beyond our control, could result in the suspension or termination of our operations and subject us to administrative, civil and criminal penalties and damages as well as corrective action costs.

We face community opposition from certain parties with respect to our development of the Beetaloo and related operations, which could result in significant costs and delays and could impede our ability to obtain the government approvals required for such operations.

We have been the target of protests and adverse publicity from certain parties due to concerns about our operations with respect to environmental issues or Indigenous rights, and there is an ongoing risk from existing or future community opposition to our operations. For example, pastoralists whose pastoral leases are subject, in part, to our petroleum interests may refuse to enter into access agreements for us to conduct certain regulated activities that require an access agreement, and we may be required to make applications to the relevant tribunal to obtain access agreements for such regulated activities.

Disapproval from local communities or other interested parties may lead to direct action that could impede our ability to carry out our operations, resulting in project delay, reputational damage and increased costs, and thus impact our financial performance. Such community opposition may include undertaking legal proceedings (including challenges to required governmental approvals) seeking orders to prevent part or all of our operations, media campaigns and protests, which could result in significant legal costs and delays. If such community members were successful in their campaigns, operations may be suspended or we may not be able to obtain the permits and approvals or there could be delay in obtaining the permits and approvals we will need to carry out our commercial operations.

The exploration and development of natural gas in the Beetaloo can pose native title and heritage risks, potentially leading to legal disputes, operational disruptions, and reputational damage.

We are required to comply with the Native Title Act 1993 (Cth), and we operate on areas in which native title has been judicially determined to exist. Consultation and negotiations have occurred, leading to the development of exploration agreements with native title holders. Further agreements will be required for any production phase, but the exploration agreements anticipate production and provide the parameters for those negotiations and outcomes. We will also be required to comply with the ALRA for tenement applications over Aboriginal land (i.e., freehold land held by an Aboriginal Land Trust under the ALRA, or land subject to a deed of grant held in escrow by an Aboriginal Land Council under the ALRA). Compliance with either legislative regime and their respective requirements for negotiation and agreement can significantly delay the grant of exploration and production tenements, and substantial compensation may be payable as part of any agreement reached. Applications for exploration tenements over Aboriginal land can also be placed into moratorium for five years at a time under the ALRA (unless the Governor-General of Australia declares by proclamation that the Australian national interest requires that the license be granted). These legislative regimes may impact our existing or future activities, ability to develop projects and operational and financial performance. Additionally, we cannot guarantee that all stakeholders will agree that our negotiations have been conducted consistent with the principle recognized in the United Nations Declaration on the Rights of Indigenous Peoples (UNDRIP) and People of Free, Prior and Informed Consent (FPIC), which may result in operational, reputational, or other adverse impacts to our business.

In addition, we will also need to comply with the Sacred Sites Act 1989 (NT), the Heritage Act 2011 (NT), the Aboriginal and Torres Strait Islander Heritage Protection Act 1984 (Cth) and the ALRA in relation to sacred sites and certain matters of Aboriginal cultural heritage. Sacred sites and Aboriginal cultural heritage have been identified within areas covered by the tenements in which we have an interest, and other such sites may exist. It is an offense under Part IV of the Sacred Sites Act 1989 (NT) to enter onto or remain on, carry out work on or use, or desecrate a sacred site without authority. All sacred sites are protected under the Sacred Sites Act 1989 (NT), regardless of whether or not they are included on the register maintained under the Sacred Sites Act 1989 (NT). Destruction, disturbance or harming protected sites and artifacts may result in us incurring significant civil and/or criminal penalties, and reputational harm all of which may adversely impact or delay our activities. In addition, in the event of damage to sacred sites and Aboriginal cultural heritage, remediation costs may be substantive. Compliance with these laws requires significant expenditure and non-compliance may potentially result in fines and requests for improvement action from the regulator all of which may result in limitations on actions and project delays or cost overruns.

Upon entering the Safeguard Mechanism, when facility operated Scope 1 emissions exceed 100,000 t-CO2-e per annum, we are required by the Australian government to produce natural gas in the Beetaloo on a Scope 1 net zero basis. We also have set an internal net zero goal with respect to natural gas production. Meeting these requirements and goals may increase our costs of production, and we may be unable to meet these requirements and goals.

Australian law, which includes the National Greenhouse and Energy Reporting Act 2007 (Cth) and the National Greenhouse and Energy Reporting (Safeguard Mechanism) Rule 2015 (Cth) requires that, upon a facility reaching the relevant threshold of 100,000 t-CO2-e Scope 1 emissions per fiscal year, we produce natural gas in the Beetaloo on a Scope 1 net zero basis. We also have set an internal net zero goal with respect to natural gas production. To achieve these goals, we may utilize renewables and batteries to supply our operational power needs as well as purchase carbon offsets as required, however there is no guarantee we will achieve such plans. If we are unable to utilize renewables and batteries to supply our operation power needs to the extent we currently expect, if the price of carbon offsets increases or if we have otherwise underestimated the amount of Scope 1 or Scope 2 emissions that we will need to offset, our costs of production will increase further which could have a material adverse effect on the results of operations. The Australian government has announced a review of the Safeguard Mechanism, which is due to commence in the second half of calendar year 2026 and conclude during calendar year 2027. The review will consider key settings including the baseline decline rate beyond 2030 and the threshold for covered facilities.

We may not achieve, and there are potential risks associated with, our growth strategy and vision to become a net zero equity Scope 1 and 2 emissions producer. Achievement of our vision of becoming a net zero equity Scope 1 and 2 producer of gas is presently uncertain and depends on us being able to economically manage our carbon emissions, which could, for example, be impacted by availability of future revenues to fund various carbon initiatives, market pricing of carbon offsets, evolution in greenhouse gas accounting methodologies, technological developments affecting operations and costs of implementing sustainable practices. Failure, or perceived failure, to meet these or other goals or commitments regarding the environmental, social and governance (ESG) characteristics of our offerings may subject us to litigation or stakeholder activism (which may be costly) or otherwise adversely impact our business. For more information, see our risk factor titled “We are subject to risks related to corporate social responsibility, including the risk that our expectations or estimates regarding environmental, social and governance matters may not be achieved or may be incorrect.”

Attention to sustainability and ESG matters and environmental conservation measures may adversely impact our business.

Evolving expectations from regulators, investors, lenders, customers, employees and other stakeholders concerning climate change, sustainability and ESG matters, and growing consumer demand for alternative forms of energy may result in increased costs (including but not limited to increased costs related to compliance, stakeholder engagement, contracting and insurance), reduced demand for our products, reduced profits, increased investigations and litigation and negative impacts on our access to capital markets. Increasing attention to climate change, environmental justice and environmental conservation, for example, may result in demand shifts for natural gas products and additional governmental investigations and private litigation against us. To the extent that societal, political, or other factors are involved, including factors associated with geopolitical considerations, it is possible that we could be subject to changing market conditions, liability, or loss of certain assets without regard to our ultimate role in the causation of or contribution to the asserted events or damages, or to other mitigating factors.

Opposition toward natural gas drilling and development activity has been evolving globally. Companies in the natural gas industry are often the target of activist efforts from both individuals and non-governmental organizations regarding safety, environmental risk and compliance and business practices. Anti-development activists are working to, among other things, reduce access to government lands and delay or cancel certain projects such as the development of natural gas shale plays or related fossil fuel infrastructure.

Our voluntary initiatives (such as voluntary disclosures, certifications, or goals, among others) to improve the sustainability and ESG profile of our company and/or products or to respond to stakeholder expectations may be costly and may not have the desired effect. For example, we may ultimately be unable to complete certain initiatives or targets, either on the timelines initially announced or at all, due to technological or legal cost, or other constraints, which may be within or outside of our control. For example, we may undertake initiatives or disclosures based on estimates, assumptions, methodologies, or third-party information that is subsequently determined to be inaccurate, unreasonable, or to not align with best practices. Our approaches to such matters may evolve as well, but we cannot guarantee that it will necessarily align with the expectations of any particular stakeholder.

If we fail to, or are perceived to fail to, comply with or advance certain sustainability and ESG initiatives (including the timeline and manner in which we complete such initiatives), we may be subject to various adverse impacts, including reputational damage and potential stakeholder engagement and/or litigation, even if such initiatives are currently voluntary. For example, there have been allegations of greenwashing against companies making significant ESG claims due to a variety of perceived deficiencies in disclosure, methodology, or performance, including as stakeholder perceptions of sustainability continue to evolve.

In addition, we expect there will likely be diverging levels of regulation, disclosure-related and otherwise, with respect to ESG matters. For example, starting fiscal year 2027, we will become subject to mandatory climate-related disclosure requirements in Australia under the Australian Sustainability Reporting Standards (including AASB S2 Climate-related Disclosures) and the Corporations Act. We may become subject to additional mandatory climate and sustainability disclosure regimes in other jurisdictions in which we operate including, for example, the European Union’s Corporate Sustainability Reporting Directive, California’s Climate Corporate Data Accountability Act (SB 253), Climate-Related Financial Risk Act (SB 261) and analogous regimes. These regimes require us to make new and expanded disclosures regarding our climate-related governance, strategy, risk management, metrics and targets, and may differ from one another in scope, methodology, materiality threshold, and assurance requirements. Differences or perceived inconsistencies between our disclosures across these regimes, or between these disclosures and our other public statements (including our Sustainability Report) could expose us to enforcement action, private litigation, regulatory inquiry, or reputational harm. These variations may occur even where the underlying data is accurate, reflecting the application of different regulatory frameworks or the structural necessity of reporting across distinct corporate perimeters and legal entity boundaries (such as regional subsidiary-level data perimeters versus our global consolidated organizational footprint). Additionally, these new obligations will require us to incur significant additional costs to comply, including the implementation of significant additional internal controls, processes and procedures regarding matters that have not been subject to such controls in the past, and impose increased oversight obligations on our management and board of directors. These regulations are not uniform, which may increase the cost and complexity of compliance, as well as associated risks.

Simultaneously, there are efforts by some stakeholders to reduce companies’ efforts on certain ESG-related matters. Our efforts to implement or expand sustainability and ESG initiatives and programs may be viewed unfavorably by some stakeholders and expose us to competing and sometimes irreconcilable demands. Both advocates and opponents to certain ESG matters are increasingly resorting to a range of activism forms, including media campaigns and litigation, to advance their perspectives. To the extent we are subject to such activism, it may require us to incur costs or otherwise adversely impact our business. Responding to these divergent and shifting expectations on both pro-ESG and anti-ESG matters may increase our costs and operational complexity, which could lead to adverse effects on our business.

In addition, we note that standards and expectations regarding carbon accounting and the processes for measuring and counting GHG emissions and GHG emission reductions are evolving, and it is possible that our approach to measuring both our emissions and our approaches to reduce emissions may be, either currently or in the future, considered inconsistent with common or best practices with respect to measuring and accounting for such matters, reducing overall emissions and/or achieving “net zero” across any emissions scope. If our approaches to such matters fall out of step with common or best practice, we may be subject to additional scrutiny, criticism, regulatory and investor engagement or litigation, any of which may adversely impact our business, financial condition or results of operations. This and other stakeholder expectations will likely lead to increased compliance costs as well as scrutiny that could heighten all of the risks identified in this risk factor.

Organizations that provide information to investors on corporate governance and related matters have developed ratings processes for evaluating companies on their approach to sustainability and ESG matters. Such ratings are used by some investors to inform their investment and voting decisions. Unfavorable ESG ratings and recent activism directed at shifting funding away from companies with fossil fuel-related assets could lead to increased negative investor sentiment toward us and our industry and to the diversion of investment to other industries, which could have a negative impact on our access to and costs of capital. Also, institutional lenders may decide not to provide funding for fossil fuel energy companies based on climate change and natural capital related concerns, which could affect our access to capital for potential growth projects. Moreover, to the extent sustainability and ESG matters negatively impact our reputation, we may not be able to compete as effectively to recruit or retain employees, customers, or business partners. Such ESG matters may also impact our suppliers, service providers, or customers, which may adversely impact our business, financial condition, or results of operations.

Federal and local legislative and regulatory initiatives relating to hydraulic fracturing as well as governmental reviews of such activities could result in increased costs and additional operating restrictions or delays in the completion of natural gas wells and adversely affect our production.

Public debate exists regarding the potential subsurface and surface impact of unconventional drilling, including concern about the impacts of unconventional drilling for water. In addition, there are many regulatory requirements for us to adhere to including, but not limited to, those specified in the Petroleum Act 1984 (NT), Petroleum Regulations 2020 (NT), Petroleum (Environment) Regulations 2016 (NT), Water Act 1992 (NT), Environment Protection Act 2019 (NT), Environment Protection and Biodiversity Conservation Act 1999 (Cth) and the Work Health and Safety (National Uniform Legislation) Act 2011 (NT) and Work Health and Safety (National Uniform Legislation) Regulations 2011 (NT). Unconventional drilling requires large volumes of water (the availability and regulation of which may change over time) and there are costs associated with water disposal that may be required should we produce water in our wells. As more impacts of unconventional drilling are fully understood, it may be subject to additional regulations or restrictions from local, state, or federal governmental authorities, resulting in increased compliance costs. Any modification to the current requirements may adversely impact the value of our assets and future financial performance.

Our operations are subject to risks relating to climate change that could increase compliance or operating costs, limit natural gas exploration and production areas, and reduce demand for the natural gas we produce.

Climate change continues to attract considerable public and scientific attention. As a result, numerous proposals, laws, and regulations have been adopted, been considered for adoption, and are likely to continue to be made at the international, national, regional and state levels of government to monitor and limit emissions of carbon dioxide, methane and other GHGs. These efforts have included consideration of cap-and-trade programs, carbon taxes, GHG reporting and tracking programs and regulations that directly limit GHG emissions from certain sources. As a natural gas development company, we are exposed to both transition risks and physical risks associated with climate change. Transitioning to a lower-carbon economy may entail extensive policy, legal, technology and market changes and, if demand for gas declines, we will find it difficult to commercialize any resources we discover.

The transition and physical risks associated with climate change (including also regulatory responses to such issues and associated costs) may significantly affect our operating and financial performance. For example, the Australian government announced its policy to target net zero GHG emissions economy-wide by 2050. In connection with that announcement, the Australian government designated that shale natural gas facilities in the Beetaloo that exceed the relevant threshold of 100,000 gross tonnes of CO2-e emissions per fiscal year will be given a “Zero” GHG baseline. Accordingly, once a shale natural gas facility has exceeded the 100,000 gross t-CO2-e Scope 1 threshold, the Company must demonstrate that it has achieved Scope 1 net zero emissions, either through operational measures or by purchasing carbon offsets. Various policymakers have also adopted, or are considering adopting, rules to require companies to provide significantly expanded climate-related disclosures. For more information, see our risk factor titled “Attention to sustainability and ESG matters and environmental conservation measures may adversely impact our business.” In addition, climate change may give rise to physical risks to our operations, including an increased frequency or severity of natural disasters and weather events, such as bushfires, cyclones, flooding, and extreme heat, as well as chronic shifts in temperature and precipitation patterns and water availability in the Northern Territory, any of which could delay or prevent our ability to conduct our activities, which could negatively impact our financial performance.

Evolving attention to global climate change has resulted in increased risk of public and private litigation, which could increase our costs or otherwise adversely affect our business. A number of parties have commenced litigation against oil and natural gas companies in state or federal courts and tribunals, alleging, among other things, that such companies contributed to climate impacts by producing, handling or marketing fossil fuels, or violate citizens’ rights by contributing to climate change, or alleging that companies have been aware of the adverse effects of climate change for some time but failed to adequately disclose those impacts. In some jurisdictions, litigation has also been brought to establish legal mandates for particular entities to take certain climate-related actions, such as pursuing aggressive emissions reductions for their Scope 3 emissions, regardless of whether entities have established any such goals already. The ultimate outcome and impact to us of any such litigation cannot be predicted with certainty, and we could incur substantial legal costs associated with defending these and similar lawsuits in the future. Activism related to climate change has also been increasing in our industry, and both shareholders and other parties may attempt to effect changes to our business or governance, whether by stockholder proposals, public campaigns, proxy solicitations or otherwise, as applicable. Any of these risks could result in unexpected costs, negative sentiments about us, disruptions in our operations, increases to our operating costs and expenses and reduced demand for our products, which in turn could have an adverse effect on our business, financial condition and results of operations.

There are also increasing financial risks for fossil fuel producers as various capital providers may elect in the future to shift some or all of their investments into non-fossil fuel energy related sectors. Many capital providers have also incorporated more substantial assessments of climate-related matters into their funding considerations, including how such funding may impact such capital providers’ own Scope 3 emissions, and may elect not to provide, or to continue not to provide, funding to fossil fuel energy companies. While various capital providers have subsequently chosen not to invest in fossil fuel energy companies, many have stated that they continue to consider climate-related matters in their strategy and financing decisions. There is also a risk that financial institutions will be required to adopt policies that have the effect of reducing the funding provided to the fossil fuel sector. Limitation of investments in and financings for fossil fuel energy companies could result in the restriction, delay or cancellation of drilling programs or development or production activities.

Significant physical events also have the potential to damage our facilities, disrupt our production activities and cause us to incur significant costs in preparing for or responding to those effects. Climate change is expected to have an effect on the frequency or severity of weather events (including hurricanes, wildfires, droughts and floods), sea levels, the arability of farmland, changes in temperature and other meteorological patterns, and water availability and quality and our development and production operations have the potential to be adversely affected. Potential adverse effects could include damages to our facilities from powerful winds or rising waters in low lying areas, disruption of our production activities either because of climate related damages to our facilities or in our costs of operation potentially arising from such climatic effects, less efficient or non-routine operating practices necessitated by climate effects or increased costs (or decreased availability) for insurance coverage in the aftermath of such effects. Additionally, in response to changing climatic conditions, certain policymakers have proposed increased restrictions on the withdrawal and use of water for fossil fuel production or other industrial uses, which may either delay or prohibit our access to certain bodies of water; to the extent we do not have sufficient local water sources available, we may be required to incur substantial costs or curtail operations, which may become more significant in periods of drought or other water scarcity. Increasing water stress or other concerns about climate change may also increase policymakers or activists’ scrutiny on any potential impacts of our operations on local water bodies regardless of any use we make thereof. Significant physical effects of climate change could also have an indirect effect on our financing and operations by disrupting the transportation or process-related services provided by midstream companies, service companies or suppliers with whom we have a business relationship. The effects of climate change may impact the cost or availability of insurance, and even where insurance is maintained we may not be able to recover through insurance some or any of the damages, losses or costs that may result from potential physical effects of climate change. Our various actions to mitigate our business risks associated with climate change require us to incur substantial costs and may not be successful, due to, among other things, the uncertainty associated with the longer-term projections associated with managing climate related risks.

Our ability to pursue our business strategies may be adversely affected if we incur costs and liabilities due to a failure to comply with environmental, health and safety laws or regulations or a release into the environment.

Despite efforts to conduct activities in an environmentally responsible manner and in accordance with applicable laws, there is a risk that our activities may cause harm to the environment which could impact production or delay future development timetables.

We are subject to laws and regulations to minimize the environmental impact of our operations and rehabilitation or remediation of any areas affected by our operations. Changes to environmental laws may result in the cessation or reduction of our activities, materially increase development or production costs or otherwise adversely impact our operations, financial performance or prospects. Penalties for failure to adhere to requirements and, in the event of environmental damage, remediation costs can be substantial and may not, in their entirety, be covered by insurance. Compliance with these laws requires significant expenditure and non-compliance may potentially result in fines or requests for improvement action from the regulators.

In addition, if we were to be held responsible for environmental damage, in addition to remediation costs, we may suffer reputational damage, possible suspension or cessation of operations, suspension or revocation of permits, litigation risk, or financial or civil penalties.

We may incur significant costs and liabilities as a result of environmental, health and safety laws and regulations applicable to the operation of our wells, gathering systems and other facilities including, but not limited to the following laws, as amended from time to time.

• Petroleum Act 1984 (NT);
• Petroleum Regulations 2020 (NT);
• Petroleum (Environment) Regulations 2016 (NT);
• Water Act 1992 (NT);
• Environment Protection Act 2019 (NT);
• Environment Protection and Biodiversity Conservation Act 1999 (Cth);
• Northern Territory Aboriginal Sacred Sites Act 1989 (NT);
• Heritage Act 2011 (NT);
• Aboriginal and Torres Strait Islander Heritage Protection Act 1984 (Cth);
• Native Title Act 1993 (Cth);
• Aboriginal Land Rights (Northern Territory) Act 1976 (Cth);
• National Greenhouse and Energy Reporting Act 2007 (Cth);
• Work Health and Safety (National Uniform Legislation) Act 2011 (NT); and
• Waste Management and Pollution Control Act 1998 (NT).

These laws and their respective regulations, as well as state and territory laws and regulations, generally restrict the level of pollutants emitted to ambient air, discharges to surface water and disposals or other releases or threats of release to surface, soils and groundwater. Failure to comply with these laws and regulations may result in the assessment of sanctions, including administrative, civil and criminal penalties, the imposition of investigatory, remedial and corrective action obligations, the incurrence of capital expenditures, the occurrence of delays in the permitting, development or expansion of projects and the issuance of orders enjoining some or all of our future operations in a particular area. Certain environmental laws impose strict joint and several liability, without regard to fault or legality of conduct, for costs required to clean up and restore sites where hazardous substances or other wastes have been disposed of or otherwise released. Moreover, it is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the release of hazardous substances, wastes or other materials into the environment. The damages claimed may be material. In addition, these laws and regulations may restrict the rate of natural gas production or underground injection, disposal, and sequestration of carbon dioxide. There can be no assurance that our environmental compliance costs will not be material in the future or that such future compliance will not have a material adverse effect on our business and operating results.

In addition, as a result of these environmental, health and safety laws and regulations, and their impact on our operations, we rely on specialized contracted companies to perform the majority of the specialized services inherent in the oil and natural gas industry. As such, we rely on the ability of these contractors to provide trained labor and properly designed and maintained equipment unique to their services. With the cyclical nature of the oil and natural gas business, the personnel used by these specialized contractors to perform these services may differ significantly in experience levels. From time to time, these specialized contractors may use new personnel that are still in training or may further sub-contract these services to other companies or personnel. There is a risk that these sub-contractors are unqualified or under-trained or that their equipment is not properly designed or maintained, which could result in work being performed inadequately or unsafely.

Moreover, public interest in the protection of the environment has increased dramatically in recent years. The trend of more expansive and stringent environmental legislation and regulations applied to the oil and natural gas industry could continue, resulting in increased costs of doing business and consequently affecting profitability. To the extent laws are enacted or other governmental action is taken that restricts or prohibits drilling or production or imposes more stringent and costly operating, waste handling, disposal and cleanup requirements, our business, prospects, financial condition or results of operations could be materially adversely affected.

Our future gathering systems and processing, treating and fractionation facilities will be subject to regulation by the Northern Territory that could have a material adverse effect on our operations and cash flows.

NT Government regulation of gathering systems and processing, treating and fractionation facilities includes safety and environmental requirements. In addition, several of our future gas gathering systems will be subject to non-discriminatory take requirements and complaint-based regulation with respect to our rates and terms and conditions of service. Northern Territory regulation may cause us to incur additional costs or limit our operations, any or all of which could have a material adverse effect on our operations and revenue.

We may face unanticipated water and other waste disposal costs as a result of increased water-related laws and regulations.

We may be subject to laws and regulation that restrict our ability to cost effectively manage water produced as part of natural gas exploration and production operations. The process of shale extraction involves the injection of stimulation fluid involving water and the recovery of that stimulation fluid to enable gas flows. This water is referred to as flowback. Other waste water is produced during drilling, with drilling and flowback wastewater collectively referred to as “wastewater”. Our ability to manage wastewater may impact our ability to undertake exploration and production activities. Wastewater must be either recycled within stimulations or evaporated onsite prior to transport and disposal of any remaining wastewater. The cost to transport and dispose of that water, including the cost of complying with regulations concerning water disposal, may reduce our profitability. Where wastewater produced from our projects fails to meet the quality requirements of applicable regulatory agencies, our wells produce wastewater in excess of the applicable volumetric permit limits or the quality is not suitable for recycling, we may have to shut in wells, reduce drilling activities, or upgrade facilities for wastewater handling or treatment. The costs to dispose of this produced water may increase if any of the following occur:

• we cannot obtain future permits from applicable regulatory agencies;
• water of lesser quality or requiring additional treatment is produced;
• our wells produce excess water;
• new laws and regulations require water to be disposed in a different manner; or
• costs to transport the produced wastewater to the disposal wells increase.

Restrictions on drilling, completion, production or related activities intended to protect certain species of wildlife may adversely affect our ability to conduct drilling activities in some of the areas where we operate.

Natural gas operations in our operating areas can be adversely affected by seasonal or permanent restrictions on drilling activities designed to protect various wildlife, such as those restrictions imposed under the Environment Protection Act 2019 (NT) or the Environment Protection and Biodiversity Conservation Act 1999 (Cth) (the EPBC Act). Seasonal restrictions may limit our ability to operate in certain protected areas and can intensify competition for drilling rigs, oilfield equipment, services, supplies and qualified personnel, which may lead to periodic shortages when drilling is allowed. These constraints and the resulting shortages or high costs could delay our operations and materially increase our operating and capital costs. Permanent restrictions imposed to protect endangered species could prohibit drilling in certain areas or require the implementation of expensive mitigation measures. The designation of previously unprotected species in areas where we operate as threatened or endangered could cause us to incur increased costs arising from species protection measures or could result in limitations on our exploration, development and production activities that could have an adverse impact on our ability to develop and produce our reserves. To the extent species are listed or re-designated under the EPBC Act, or previously unprotected species are designated as threatened or endangered in areas where our properties are located, operations on those properties could incur increased costs arising from species protection measures and face delays or limitations with respect to production activities thereon. There is also increasing interest in nature-related matters beyond protected species, such as general biodiversity, which may similarly require us to incur costs or take other measures which may materially impact our business or operations.

Our business is subject to complex and evolving laws and regulations regarding privacy, data security and the processing of personal information.

In connection with running our business, we handle information that relates to individuals and/or constitutes “personal information” or similar terms under applicable data privacy laws, including from and about business contacts, employees, investors, and website users. We also depend on third party vendors in relation to the operation of our business, a number of which process personal information on our behalf. We and our vendors are therefore subject to various federal, state, and foreign laws, regulations and other requirements relating to the privacy, security and handling of personal information. For example, certain laws and regulations impose transparency obligations, provide residents with rights in relation to their personal information, and impose restrictions on our disclosure of their information.

These requirements, and their application, interpretation and amendment, are constantly evolving and pose increasingly complex compliance challenges. It is also possible that new laws, regulations and other requirements, or amendments to or changes in interpretations of existing laws, regulations and other requirements, may require us to implement new processes, potentially elevate our costs, or require changes to our handling of information or our operations. Further, legislative activity and regulatory focus on data privacy and security, including in relation to cybersecurity incidents, have significantly increased in the United States and globally. Some such requirements restrict our ability to process personal information across our business and across country borders. Any failure or perceived failure by us to comply with laws, regulations, industry standards and requirements regarding data privacy, data security or the processing of personal information could result in proceedings or actions against us by individuals, consumer rights groups, government agencies, or others. We continue to monitor and assess the impact of these laws, regulations and other requirements, but we could incur significant costs in investigating and defending such claims, and any subsequent adverse outcomes may subject us to significant negative publicity and an erosion of trust. If any of these events were to occur, our business, results of operations, and financial condition could be materially adversely affected.

Risks Related to our Corporate Structure

We are a holding company. Our sole material asset is our equity interest in TR Ltd., and we will be accordingly dependent upon distributions from TR Ltd. 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 TR Ltd. See “Business and Properties—General Development of Business and Corporate Reorganization.” We have no independent means of generating revenues. To the extent TR Ltd. has available cash, we intend to cause TR Ltd. to make distributions to us, in an amount at least sufficient to allow us to pay our taxes and reimburse us for our corporate and other overhead expenses. We may be limited, however, in our ability to cause TR Ltd. and its subsidiaries to make these and other distributions or payments to us due to certain limitations, including the cash requirements and financial condition of TR Ltd. and restrictions in any relevant debt instruments entered into by TR Ltd. or its subsidiaries and/or other entities in which it directly or indirectly holds an equity interest. To the extent that we need funds and TR Ltd. or its subsidiaries are restricted from making such distributions or payments under applicable laws or regulations or under the terms of any future financing arrangements, or are otherwise unable to provide such funds, our liquidity and financial condition could be materially adversely affected.

We may be unable to achieve some or all of the benefits that we expect to achieve from the Corporate Reorganization, which could materially adversely affect our business, financial condition and results of operations.

We may not be able to achieve the full strategic and financial benefits expected to result from the Corporate Reorganization, or such benefits may be delayed or not occur at all. We may not achieve these and other anticipated benefits for a variety of reasons, including, among others, because we may experience unanticipated competitive developments, including changes in the conditions of industry and the markets in which we operate, including fluctuations in the prices of natural gas that could negate some or all of the expected benefits from the Corporate Reorganization.

If we do not realize some or all of the benefits expected to result from the Corporate Reorganization, or if such benefits are delayed, our business, expected future financial and operating results and our prospects could be adversely affected.

Risks Related to Environmental, Legal Compliance and Regulatory Matters (Hungary)

If, upon expiry of the currently effective production TOP period in July 2027, the minimum production threshold set out in Section 30/A(3)–(4) of the Mining Act is not met (i.e., planned natural gas production during such period totals 225,500m³) the mining plot will be cancelled. SZTFH resolution approving the 2026/2027 TOP for the Makó-árok I. mining plot (resolution no. SZTFH-BANYASZ/5240-11/2026) expressly provides that the mining authority will cancel TXM's mining right if the production volumes authorized thereunder are not achieved. Among other obligations and restrictions, the mining authority has not authorized in the TOP approval decision hydraulic fracturing, formation acidizing, gas injection, formation energy replenishment, or water injection for the purposes of hydraulic fracturing or formation energy replenishment.

If the mining plot is cancelled, it is the obligation of the former holder of the mining plot to fulfill, among others, compensation obligations for mining damage (if any), complying with statutory requirements of land remediation and safety, as well as protection of the environment and nature shall be maintained. Accordingly, in case of cancellation the plugging and abandonment of the existing wells will be the obligation of TXM, the ordering of which may be subject to the tendering process described below.

Following cancellation, the mining authority may launch a public tender for the reallocation of the mining plot; however, the duration of such process cannot be estimated in advance. As long as the possibility of re-tendering remains open, the final plugging and abandonment of the wells would normally not be expected (it is not excluded though), as a new license holder may wish to make use of some of the existing wells.

Exploration and production of hydrocarbons in Hungary are governed by a complex and evolving framework of laws and regulations, primarily the Mining Act, environmental protection legislation, nature conservation rules, water management regulations and related secondary legislation. These rules include requirements concerning, inter alia, the authorization and conduct of mining activities, environmental protection, nature conservation, water management and site rehabilitation.

Operators must obtain and maintain a range of permits, approvals and rights, as applicable, including mining rights or concessions, environmental authorizations, environmental impact assessments where required, water abstraction and discharge permits, and land-use rights (surface land access must still be secured separately from the mining rights). Material expenditures are typically required for royalties, financial security for decommissioning and rehabilitation, environmental monitoring, reporting obligations and compliance with the approved technical operational plan. Land access arrangements with surface owners and, where applicable, engagement with local authorities or other stakeholders add further complexity and potential delay.

Drilling and well-work operations, other than maintenance activities, must be notified to the mining authority prior to commencement and may only begin once the designated responsible technical manager has confirmed operational readiness and the required approval is recorded in the mine's safety log. Production from continuously operating wells must be measured at least monthly. Temporarily suspended wells must be secured and regularly inspected under an operator-approved plan; permanently abandoned wells must be securely closed and abandoned in accordance with the applicable mining and technical safety requirements.

Non-compliance with applicable laws, license conditions or environmental standards may result in suspension or termination of operations, revocation or non-renewal of mining rights, substantial administrative fines, civil liability for environmental damage or personal injury, and in serious cases criminal sanctions. Such outcomes could impair the ability to commercialize or retain assets and may have a material adverse effect on operational and financial performance. In addition, acquired assets may carry pre-existing environmental or rehabilitation liabilities that could give rise to further costs or restrictions.

The mining right may be cancelled in particular if the holder fails to provide the required financial security and, following a final authority decision prohibiting the commencement or continuation of mining operations until such security is provided, fails to provide such security within ninety days, or if, within two years following the first sanctioned infringement, the holder commits three further infringements, resulting in cancellation of the mining right upon the fourth infringement, or if operative production, as defined by applicable law, is not commenced within five years of the establishment of the mining plot, or the fee prescribed for the extension of that period is not paid; or if the mining right holder ceases to exist without a legal successor.

Acquisition of a controlling or other qualifying interest in a Hungarian company that holds a mining plot requires the prior approval of the mining authority under the Mining Act. Non-compliance with either requirement renders the acquisition void as regards the mining rights.

Government policy in the energy sector is subject to change and may be influenced by European Union climate and energy-transition objectives, domestic security-of-supply considerations or fiscal measures. Shifts in policy could lead to tighter environmental standards, increased royalties, new restrictions on production, or changes to the concession and licensing regime. The grant or extension of production rights remains discretionary and may be made subject to conditions that affect profitability or operational flexibility.

In addition, operations may be constrained by protected areas, water-resource limitations or other environmental features. Any failure to adapt to new or stricter requirements, or any delay in obtaining necessary authorizations, could increase costs, prolong project timelines or limit the scope of activities, thereby adversely affecting results of operations and financial conditions.

Risks Related to our Common Stock and our CDIs

The requirements of being a public company, including compliance with the reporting requirements of the ASX listing rules and the Exchange Act, may strain our resources, increase our costs and distract management, and we may be unable to comply with these requirements in a timely or cost-effective manner.

As our CDIs are publicly traded in Australia and our common stock is publicly traded in the United States, we need to comply with laws, regulations and requirements, certain corporate governance provisions of SOX, related regulations of the SEC and the requirements of the ASX and NYSE. Complying with these statutes, regulations and requirements occupies a significant amount of our time and causes us to incur significant costs and expenses.

If, however, we do not follow those procedures and policies, or they are not sufficient to prevent non-compliance, we could be subject to liability, fines and lawsuits. These laws, regulations and standards are subject to varying interpretations and, as a result, their application in practice may evolve over time as new guidance is provided by regulatory and governing bodies. Our investment in resources to comply with evolving laws, regulations and standards may result in increased general and administrative expenses and a diversion of management’s time and attention from revenue generating activities to compliance activities. If we fail to comply with new laws, regulations and standards, regulatory authorities may initiate legal proceedings against us, and our business may be harmed.

Changes in foreign currency exchange rates could materially adversely affect our business, results of operations or financial condition.

In our operations, there are transactions and balances denominated in currencies other than the U.S. dollar (which is the currency used to report our results of operations and financial condition in our financial statements), consisting primarily of the Australian dollar. To the extent our assets and liabilities denominated in Australian dollars as of June 30, 2026 are not hedged, we estimate that a 5% change in the exchange rate versus the U.S. dollar would expose us to foreign currency gains or losses of $48.3 million.

In addition, all of our facilities are located in Australia, a majority of our officers and employees are residents in Australia and a material proportion of our expenses are payable in Australian dollars. In the event that the U.S. dollar weakens compared with the Australian dollar, our results of operations or financial condition may be adversely affected, perhaps substantially.

We have engaged in transactions with our affiliates and expect to do so in the future. The terms of such transactions and the resolution of any conflicts that may arise may not always be in our or our stockholders’ best interests.

We have engaged in transactions and expect to continue to engage in transactions with affiliated companies. Related party transactions can create the possibility of conflicts of interest with regard to our management. Such a conflict could cause an individual in our management to seek to advance his or her economic interests above ours. Further, the appearance of conflicts of interest created by related party transactions could impair the confidence of our investors. The Audit & Risk Management Committee of our board of directors (“Audit & Risk Management Committee”) reviews related party transactions in accordance with our related party transaction policy; however, review of related party transactions by our Audit & Risk Management Committee does not mean such transactions will have the expected benefits and, as such, could have an adverse impact on our financial condition or results of operations.

Certain of our affiliates are participants in joint ventures or may have other rights with respect to properties in which we have interests. For instance, Daly Waters, which is controlled by Mr. Bryan Sheffield, is an equal owner of TB1 that owns our interests in EPs 76, 98 and 117. Certain actions, such as a sale of property or incurrence of indebtedness, will require the approval of Daly Waters or its representatives on the board of TB1. In addition, we have granted Daly Waters Royalty, which is controlled by Mr. Bryan Sheffield, and certain of our directors ORRIs in certain of the permits we have interests in. On May 12, 2025, TR West, as seller, and the Company, as seller guarantor, and DWE entered into an Asset Sale Agreement. See “Business and Properties—Agreements Relating to the Development of our Assets” in this report and “Related Person Transactions” included in the 2026 Proxy Statement for further information.

Our certificate of incorporation and bylaws, as well as Delaware law, contain provisions that could discourage acquisition bids or merger proposals, which may adversely affect the market price of our CDIs and common stock.

Our certificate of incorporation authorizes our board of directors to issue preferred stock without stockholder approval. If our board of directors elects to issue preferred stock, it could be more difficult for a third-party to acquire us. In addition, some provisions of our certificate of incorporation and bylaws could make it more difficult for a third-party to acquire control of us, even if the change of control would be beneficial to our stockholders, including:

• limitations on the removal of directors;
• our classified board of directors with directors serving staggered three-year terms;
• limitations on the ability of our stockholders to call special meetings;
• establishing advance notice provisions for stockholder proposals and nominations for elections to the board of directors to be acted upon at meetings of stockholders;
• the requirement that the affirmative vote of the holders of at least 662⁄3% in voting power of all the then-outstanding shares of our stock be obtained to amend and restate our existing bylaws or to remove directors;
• the requirement that the affirmative vote of the holders of at least 662⁄3% in voting power of all the then-outstanding shares of our stock be obtained to amend our certificate of incorporation;
• providing that the board of directors is expressly authorized to adopt, or to alter or repeal our bylaws; and
• establishing advance notice and certain information requirements for nominations for election to our board of directors or for proposing matters that can be acted upon by stockholders at stockholder meetings.

Our certificate of incorporation designates the Court of Chancery of the State of Delaware as the sole and exclusive forum for certain types of actions and proceedings that may be initiated by our stockholders, which could limit our stockholders’ ability to obtain a favorable judicial forum for disputes with us or our directors, officers, employees or agents.

Our certificate of incorporation provides that, to the fullest extent permitted by law, and unless we consent in writing to the selection of an alternative forum, the Court of Chancery of the State of Delaware (or, in the event that the Chancery Court does not have jurisdiction, the Superior Court of the State of Delaware (Complex Commercial Litigation Division) or the federal district court for the District of Delaware) will be the sole and exclusive forum for any claims that (i) are based upon a violation of a duty by a current or former director or officer or stockholder in such capacity or (ii) as to which Title 8 of the Delaware Code confers jurisdiction upon the Court of Chancery, in each such case subject to such Court of Chancery having personal jurisdiction over the indispensable parties named as defendants therein. Section 22 of the Securities Act creates concurrent jurisdiction for federal and state courts over all suits brought to enforce any duty or liability created by the Securities Act or the rules and regulations thereunder. However, our certificate of incorporation provides that federal district courts of the United States of America will be the sole and exclusive forum for claims under the Securities Act. Section 27 of the Exchange Act creates exclusive federal jurisdiction over all suits brought to enforce any duty or liability created by the Exchange Act or the rules and regulations thereunder. As a result, the forum provision in our certificate of incorporation will not apply to suits brought to enforce any duty or liability created by the Exchange Act or any other claim for which the federal courts have exclusive jurisdiction. We will inform our investors in each report filed in accordance with the Exchange Act in which we describe the terms of our common stock that the forum provision in our certificate of incorporation will not apply to suits brought to enforce any duty or liability created by the Exchange Act or any other claim for which the federal courts have exclusive jurisdiction.

These provisions may have the effect of discouraging lawsuits against us or our directors, officers, employees or agents. Any person or entity purchasing or otherwise acquiring any interest in shares of capital stock of the Company will be deemed to have notice of and consented to the forum provisions in our certificate of incorporation. However, the enforceability of similar forum provisions in other companies’ certificates of incorporation has been challenged in legal proceedings, and it is possible that a court could find these types of provisions to be unenforceable. In this regard, stockholders may not be deemed to have waived our compliance with the federal securities laws and the rules and regulations thereunder, including Section 22 of the Securities Act. If a court were to find these provisions of our certificate of incorporation 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, financial condition or results of operations.

We do not expect to generate positive cash flow until at least 2028. As a result we do not expect to pay dividends on our CDIs or common stock in the foreseeable future. Consequently, the ability of CDI holders and common stockholders to achieve a return on investment will depend on appreciation in the trading price of our CDIs and common stock.

We do not anticipate generating positive cash from operations until 2028, at the earliest. Additionally, at such time we do generate positive cash flow, we anticipate that we will retain all of our future earnings for use in the operation of our business and for general corporate purposes. As a result, we do not expect to pay dividends on our CDIs or common stock in the foreseeable future. Any determination to pay dividends in the future will be at the sole discretion of our board of directors. Accordingly, investors must rely on sales of their CDIs or common stock after price appreciation, which may never occur, as the only way to realize any future gains on their investments.

We may issue preferred stock whose terms could adversely affect the voting power or value of our CDIs and common stock.

Our certificate of incorporation authorizes us to issue, without the approval of our stockholders, one or more classes or series of preferred stock having such designations, preferences, limitations and relative rights, preferences over our common stock respecting dividends and distributions, as our board of directors may determine. The terms of one or more classes or series of preferred stock could adversely impact the voting power or value of our common stock. For example, we might grant holders of preferred stock the right to elect some number of our directors in all events or on the happening of specified events or the right to veto specified transactions. Similarly, the repurchase or redemption rights or liquidation preferences we might assign to holders of preferred stock could affect the residual value of our common stock.

We have identified a material weakness in our internal control over financial reporting. Any material weakness may cause us to fail to timely and accurately report our financial results or result in a material misstatement of our financial statements.

Subject to applicable reporting requirement exemptions we take advantage of as an emerging growth company, we are required to comply with the SEC rules implementing Sections 302 and 404 of the SOX, which require management to certify financial and other information in our quarterly and annual reports and provide an annual management report on the effectiveness of controls over financial reporting. Effective internal control over financial reporting is necessary for us to provide reliable and timely financial reports and, together with adequate disclosure controls and procedures, are designed to reasonably detect and prevent fraud. We are also required to report any material weaknesses in such internal control. 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 our financial statements will not be prevented or detected on a timely basis.

In connection with the preparation of our financial statements for the fiscal years ended June 30, 2026 and 2025, we identified deficiencies in our internal control over financial reporting which, in the aggregate, constituted a material weakness as of June 30, 2026. The deficiencies that continue to exist as of June 30, 2026 relate to insufficiently designed and operating internal control over financial reporting and consist of the following: (i) we failed to effectively document management review procedures to validate the completeness and accuracy of transactions and to clearly define and evidence the processes used and the criteria and judgment applied in the performance of critical business processes; and (ii) we failed to fully resolve identified segregation of duties conflicts with system access for designated business and IT privileged users, and as a result the related user access and application change management procedures could not be relied upon for select Company systems.

If our steps are insufficient to successfully remediate the material weakness and otherwise establish and maintain an effective system of internal control over financial reporting, the reliability of our financial reporting, investor confidence in us, and the value of our common stock could be materially and adversely affected. Our failure to implement and maintain effective internal control over financial reporting could result in errors in our financial statements that could result in a restatement of our financial statements or cause us to fail to meet our periodic reporting obligations. For as long as we are an “emerging growth company” under the JOBS Act, our independent registered public accounting firm will not be required to attest to the effectiveness of our internal control over financial reporting pursuant to Section 404.

Once we no longer qualify as an “emerging growth company,” we will be required to have our independent registered public accounting firm provide an attestation report on the effectiveness of our internal control over financial reporting. An independent assessment of the effectiveness of our internal control over financial reporting could detect problems that our management’s assessment might not. Undetected material weaknesses in our internal control over financial reporting could lead to financial statement restatements and require us to incur the expense of remediation. An adverse report may be issued if our independent registered public accounting firm is not satisfied with the level at which our controls are documented, designed or operating.

We cannot be certain that our efforts to develop and maintain our internal controls will be successful, that we will be able to maintain adequate controls over our financial processes and reporting in the future or that we will be able to comply with our obligations under Section 404 of the SOX. Any failure to develop or maintain effective internal controls, or difficulties encountered in implementing or improving our internal controls, could harm our operating results or cause us to fail to meet our reporting obligations. Ineffective internal controls could also cause investors to lose confidence in our reported financial information, which would likely have a negative effect on the trading price of our CDIs and common stock.

For as long as we are an emerging growth company, we will not be required to comply with certain reporting requirements, including those relating to accounting standards and disclosure about our executive compensation, which apply to other public companies.

We are classified as an “emerging growth company” under the JOBS Act. For as long as we are an emerging growth company, which may be up to five full fiscal years, unlike other public companies, we will not be required to, among other things, (i) provide an auditor’s attestation report on management’s assessment of the effectiveness of our system of internal control over financial reporting pursuant to Section 404(b) of the Sarbanes-Oxley Act, (ii) comply with any new requirements adopted by the Public Company Accounting Oversight Board requiring mandatory audit firm rotation or a supplement to the auditor’s report in which the auditor would be required to provide additional information about the audit and the financial statements of the issuer, (iii) provide certain disclosure regarding executive compensation required of larger public companies or (iv) hold nonbinding advisory votes on executive compensation. We will remain an emerging growth company for up to five years, although we will lose that status sooner if we have more than $1.235 billion of revenues in a fiscal year, have more than $700.0 million in market value of our common stock held by non-affiliates or issue more than $1.0 billion of non-convertible debt over a three-year period.

We anticipate losing our “emerging growth company” status in the next fiscal year and we will be subject to additional public company reporting and disclosure requirements that may increase our legal and compliance costs.

Under the current SEC regulations, we anticipate losing our “emerging growth company” status in the next fiscal year. Once we lose this status, we will no longer be able to take advantage of some or all of the exemptions described above and may be required to, among other things, (i) provide three years of audited financial statements and three years of management’s discussion and analysis of financial condition and results of operations disclosure, (ii) comply with the auditor attestation requirement in the assessment of our internal control over financial reporting pursuant to Section 404 of the Sarbanes-Oxley Act (if we are an accelerated filer or large accelerated filer at that time), (iii) comply with any requirement that may be adopted by PCAOB, (iv) comply with certain disclosure and voting obligations regarding executive compensation and (v) adopt revised or new accounting standards on the time schedule applicable to non-emerging growth companies. Any new obligations will make other aspects of our business more difficult, time-consuming or costly and increase demand on our personnel, systems and other resources. For example, to maintain and improve the effectiveness of our disclosure controls and procedures and internal control over financial reporting, we will need to commit significant resources, hire additional staff and provide additional management oversight.

To the extent that we rely on any of the exemptions available to emerging growth companies, you will receive less information about our executive compensation and internal control over financial reporting than issuers that are not emerging growth companies. If some investors find our common stock to be less attractive as a result, there may be a less active trading market for our common stock and our stock price may be more volatile.

Because we have elected to take advantage of the extended transition period pursuant to Section 107 of the JOBS Act, our financial statements may not be comparable to those of other public companies.

Section 107 of the JOBS Act provides that an emerging growth company can use the extended transition period provided in Section 7(a)(2)(B) of the Securities Act for complying with new or revised accounting standards. This permits an emerging growth company to delay the adoption of certain accounting standards until those standards would otherwise apply to private companies. We are choosing to take advantage of this extended transition period and, as a result, we will comply with new or revised accounting standards on the relevant dates on which adoption of such standards is required for private companies. Accordingly, our financial statements may not be comparable to companies that comply with public company effective dates, and our stockholders and potential investors may have difficulty in analyzing our operating results by comparing us to such companies.

Our outstanding CDIs are listed on the ASX and are freely tradable in the public markets in Australia. Trading in our CDIs may have a material adverse effect on the trading price of our common stock on the NYSE.

Our common stock is traded on the NYSE and our CDIs are traded on ASX. The CDIs are, in general, the economic equivalent of shares of our common stock and, as a result, the trading price of the CDIs on the ASX likely affects the trading price of our common stock on the NYSE, and vice versa. The trading price of the CDIs may be influenced by factors different from those that affect the trading price of our common stock on the NYSE and, as discussed below in these risk factors, may be influenced by arbitrage activities. In addition, holders of shares of our common stock may deliver those shares to the depositary for the CDIs in exchange for CDIs.

Trading in our securities on these markets takes place using different currencies (U.S. dollars on NYSE and Australian dollars on the ASX), and at different times (resulting from different time zones, trading days and public holidays in the United States and Australia). The trading prices of our securities on these two markets may differ due to these and other factors, including the fact that ASX and NYSE have different criteria for trading halts as well as different listing rules and disclosure requirements. Any decrease in the price of our CDIs on the ASX could cause a decrease in the trading price of our common stock on the NYSE.

The different characteristics of the capital markets in Australia and the United States may negatively affect the trading prices of our CDIs and common stock and may limit our ability to take certain actions typically performed by a U.S. company.

We are subject to ASX listing rules with respect to our CDIs, and associated Australian regulatory requirements, and concurrently list our shares on the NYSE as well, which has its own listing and regulatory requirements. Such exchanges have different trading hours, trading characteristics (including trading volume and liquidity), trading and listing rules, and investor bases (including different levels of retail and institutional participation). As a result of these differences, the trading prices of our CDIs and our common stock may not be the same, even allowing for currency differences. Fluctuations in the price of our common stock due to circumstances peculiar to the U.S. capital markets could materially and adversely affect the price of the CDIs, or vice versa. Certain events having significant negative impact specifically on the Australian capital markets may result in a decline in the trading price of our common stock notwithstanding that such event may not impact the trading prices of securities listed in the United States generally or to the same extent, or vice versa.

In addition, any shares of common stock received in exchange for CDIs will be considered restricted securities (as that term is defined in Rule 144 of the Securities Act) and will bear a legend restricting transfer. Holders must cause the restrictive legend to be removed from such shares of common stock in order for the shares to be freely transferable and eligible to trade on the NYSE. As a result, holders of CDIs may not initially be able to freely trade into U.S. public markets, which may result in trading price differences between our common stock on the NYSE and our CDIs on the ASX.

Our ability to raise additional capital may be significantly limited by listing rules of the ASX that limit the amount of common stock that we are permitted to issue without stockholder approval.

Limitations on new share issuances under ASX listing rules may significantly limit or prevent us from raising additional capital by issuing and selling shares of our common stock or other securities when such additional capital is required. In particular, the ASX listing rules will prohibit us from issuing, during any 12-month period, shares of our common stock in an amount greater than 15% of the total number of shares of our common stock then outstanding without the affirmative vote of the holders of a majority of the outstanding shares of our common stock. As discussed elsewhere in this report, we will require substantial additional financing to develop and commercialize our resources and execute our strategy and, because we do not have any revenues from natural gas sales and would likely be unable to raise capital by borrowing funds, we will be dependent primarily upon issuing and selling additional shares of common stock to obtain such financing. The foregoing listing rule of the ASX is substantially more restrictive than the comparable NYSE rule and, even with the approval of our shareholders to permit us to issue up to 25% of the total number of shares of our common stock then outstanding during the 12-month period commencing on the date we are admitted to the official list of the ASX, this rule may significantly limit or prevent us from raising funds by issuing and selling shares of our common stock, which may have a material adverse effect on our results of operations, financial condition and the development of our business. Moreover, seeking shareholder approval to issue common stock is likely to take considerable time and expense and there can be no assurance that any such approval will be given in the future.

An investor may have limited ability to bring an action against us or against our directors and officers, or to enforce a judgment against us or them, because we conduct a majority of our operations in Australia, and many of our directors and officers reside outside the United States.

We conduct substantially all of our operations in Australia. Many of our directors and officers and certain other persons named in this report are citizens and residents of countries other than the United States and a portion of the assets of the directors and officers and certain other persons named in this report and substantially all of our assets are located outside of the United States. As a result, it may not be possible or practicable for you to effect service of process within the United States upon such persons or to enforce against them or against us judgments obtained in U.S. courts predicated upon the civil liability provisions of the federal securities laws of the United States. Even if you are successful in bringing such an action, there is doubt as to whether Australian courts would enforce certain civil liabilities under U.S. securities laws in original actions or judgments of U.S. courts based upon these civil liability provisions. In addition, awards of punitive damages in actions brought in the United States or elsewhere may be unenforceable in Australia or elsewhere outside the United States. An award for monetary damages under U.S. securities laws would be considered punitive if it does not seek to compensate the claimant for loss or damage suffered and is intended to punish the defendant. The enforceability of any judgment in Australia will depend on the particular facts of the case as well as the laws and treaties in effect at the time. The United States and Australia do not currently have a treaty or statute providing for recognition and enforcement of the judgments of the other country (other than arbitration awards) in civil and commercial matters. As a result, our holders of our common stock may have more difficulty in protecting their interests through actions against us, our management or our directors than would shareholders of a corporation operating within the United States.

As a result of listing CDIs on the ASX, we are subject to the listing rules of the ASX, which may strain our resources, divert management’s attention and affect our ability to manage our business or raise additional capital.

As a result of listing CDIs on the ASX, we are subject to the listing rules of the ASX, which may strain our resources, divert management’s attention and affect our ability to manage our business or raise additional capital. The listing rules of the ASX differ from, and in some cases are more restrictive than, the rules and requirements of the NYSE, including restrictions that:

• limit non-executive director compensation to a maximum amount approved by shareholders at a general meeting;
• require that the terms of every class of our securities, including any preferred stock, be approved by the ASX;
• prohibit us from removing or changing the voting rights or dividend rights (if any) of our securities, except in certain circumstances;
• specify certain terms and conditions of options and rights plans;
• prohibit issuing equity securities without shareholder approval in the three months after we receive any notice in writing that a person proposes to make a takeover bid;
• limit the issuance of restricted (escrowed) securities; and
• prohibit “golden parachutes” or other termination benefits for officers upon a change in ownership or control of us.

These listing rules may, in some cases, limit our ability to take certain actions that would otherwise be permitted by NYSE rules and may affect our ability to manage our business and to attract and retain key management and scientific personnel. In addition, the listing rules of the ASX include approval and reporting requirements that differ from the requirements under the NYSE rules, such as requirements to:

• comply with required timetables for issuance of equity securities;
• deliver notice to the ASX prior to the release of restricted (escrowed) securities;
• file quarterly, half-yearly and annual periodic reports that include specific disclosure required by the listing rules of the ASX;
• obtain stockholder approval for certain related-party transactions and for securities issuances to directors;
• deliver drafts to the ASX of charter documents, debt and convertible securities documents, certain meeting notices and documents sent to certain holders of securities; and
• prior to release to any other person, release announcements through the ASX as the central collection point for market sensitive information.

Compliance with these additional rules will increase our legal and financial compliance costs, make some activities or transactions more difficult, time-consuming or costly, may limit or prevent us from raising additional capital by issuing and selling shares of our common stock or other securities and increase demand on our systems and resources. We applied to the ASX for, and received, certain waivers from the application of some of its listing rules; however, such waivers will not afford us relief from all of the increased restrictions and requirements imposed by such listing rules. Increases in our costs and expenses associated with compliance with the ASX listing rules will adversely impact our results of operations and financial condition. In addition, limitations on new share issuances under ASX listing rules may limit or prevent us from raising additional capital by issuing and selling shares of our common stock or other securities when such additional capital is required, which may have a material adverse effect on our results of operations, financial condition and the development of our business. See “—Our ability to raise additional capital may be significantly limited by listing rules of the ASX that limit the amount of common stock that we are permitted to issue without stockholder approval.”

The market price of our common stock may be adversely affected by arbitrage activities.

Investors may seek to profit by exploiting the difference, if any, in the price of our shares of common stock as reflected by the trading price of our CDIs, which represent shares of our common stock, on the ASX and the trading price of our shares of common stock on the NYSE. Such arbitrage activities could cause the price of our common stock or the CDIs representing our common stock, as the case may be, in the market with the higher value to decrease to the price set by the market with the lower value or could otherwise adversely affect the market price of our common stock. These arbitrage risks may be increased by the fact that our common stock is quoted in U.S. dollars on the NYSE while our CDIs are quoted in Australian dollars on the ASX, which may also give investors the opportunity to exploit the impact of fluctuations in currency exchange rates on the market price of our common stock and the CDIs.

Changes in accounting standards issued by the Financial Accounting Standards Board (“FASB”) or other standard-setting bodies may adversely affect our financial statements.

Our financial statements are prepared in accordance with GAAP as defined in the Accounting Standards Codification (“ASC”) of the FASB. From time to time, we are required to adopt new or revised accounting standards or guidance that are incorporated into the ASC. It is possible that future accounting standards we are required to adopt could change the current accounting treatment that we apply to our consolidated financial statements and that such changes could have a material adverse effect on our financial condition and results of operations.

In addition, the FASB is working on several projects with the International Accounting Standards Board, which could result in significant changes as GAAP converges with International Financial Reporting Standards (“IFRS”), including how our financial statements are presented. Furthermore, the SEC is considering whether and how to incorporate IFRS into the U.S. financial reporting system. The accounting changes being proposed by the FASB will be a complete change to how we account for and report significant areas of our business. The effective dates and transition methods are not known; however, issuers may be required to or may choose to adopt the new standards retrospectively. In this case, issuers would report results under the new accounting method as of the effective date, as well as for all periods presented. Any such changes to GAAP or conversion to IFRS would impose special demands on issuers in the areas of governance, employee training, internal controls and disclosure and would likely affect how we manage our business.

With the guidance of the Audit & Risk Management Committee (the “Committee”), our board of directors is responsible for our risk management framework, including our strategy, policies, procedures and systems with respect to cybersecurity and information technology risks associated with us and our supply chain, suppliers and service providers. Our board of directors considers cybersecurity risk as part of its risk oversight function and has delegated to the Committee oversight of cybersecurity risks, including oversight of management’s implementation of our cybersecurity risk management program.

Our management team, including our Vice President of Information Technology, is responsible for assessing and managing our material risks from cybersecurity threats, and takes steps to stay informed about and monitor efforts to prevent, detect, mitigate, and remediate cybersecurity risks and incidents through various means, which may include information obtained from governmental, public or private sources, including external consultants engaged by us, and alerts and reports produced by security tools deployed in our IT environment. Our management team has developed and implemented a risk management program that includes cybersecurity risks as a risk category and is intended to protect the confidentiality, integrity, and availability of our critical systems and information. Management has primary responsibility for our overall cybersecurity risk management program and supervising internal staff and external consultants assisting with cybersecurity matters, including those that assist management in staying informed about cybersecurity risks and incidents. Management updates the Committee periodically on our cyber risk management program, and the Committee reports to the full board of directors regarding its activities, including those related to cybersecurity.

Our cybersecurity risk management program is integrated into our overall risk management program, and shares common methodologies, reporting channels and governance processes that apply across the risk management program to other legal, compliance, strategic, operational, and financial risk areas. Key elements of our risk management program relating to cybersecurity include: implementing risk assessments designed to help identify material risks, including risks arising from cybersecurity threats to our critical systems and information; engaging external cybersecurity consultants to assess and assist with aspects of our security processes; maintaining insurance coverage related to cybersecurity matters; and review of risks related to any new third-party IT providers based on our assessment of their criticality to our operations and respective risk profile.

Our Vice President of Information Technology has over 20 years of experience at public companies, including within the energy sector, enterprise technology vendors, and consulting firms. His expertise includes enterprise technology strategy, transformation, governance, vendor management, and operations and initiatives to strengthen cybersecurity, enhance information security posture, and mitigate technology risk. We continue to focus on cybersecurity measures as Tamboran grows.

We have not identified risks from known cybersecurity threats, including as a result of any prior cybersecurity incidents, which have materially affected us, including our operations, business strategy, results of operations, or financial condition. However, there can be no assurance that our cybersecurity risk management program and processes, including controls, systems and processes that we have or will in the future, will be fully implemented, complied with or effective in protecting our systems and information. We face risks from cybersecurity threats that, if realized, are reasonably likely to materially affect us, including our operations, business strategy, results of operations, or financial condition. See our risk factor titled “Our business could be negatively affected by security threats and disruptions, including electronic, cybersecurity or physical security threats, and other disruptions.”

Other than as described below, as of the date of this report, we are not a party to any material pending legal proceedings, nor are we aware of any material civil proceeding or government authority contemplating any legal proceeding, and to our knowledge, no such proceedings by or against us have been threatened. We anticipate that we and our subsidiaries may from time to time in the future become subject to claims and legal proceedings arising in the ordinary course of business. It is not feasible to predict the outcome of any such proceedings, and we cannot ensure that their ultimate disposition will not have a materially adverse effect on our business, financial condition, cash flows or results of operations.

On July 4, 2024, the Environment Centre Northern Territory (“ECNT”) lodged an Originating Application in the Northern Territory Civil and Administrative Appeals Tribunal (“NTCAT”) for a merits review of the Minister for Environment, Climate Change and Water Security’s (“Minister’s”) approval of TB1 Operator’s Shenandoah South Exploration & Appraisal Program EP98 and EP117 Environment Management Plan (“Shenandoah EMP”) (“NTCAT Merits Review”). On August 20, 2024, the TB1 Operator was added as a respondent to the NTCAT Merits Review. The NTCAT Merits Review was commenced by ECNT under the Petroleum Act 1984 (NT) and the Petroleum (Environment) Regulations 2016 (NT). ECNT sought an order that the Minister’s Original Decision is set aside and substituted with a decision that the Tribunal Member is not satisfied the information provided in the Shenandoah EMP is sufficiently compliant with the Petroleum (Environment) Regulations 2016 (NT), including in relation to: (a) risks of wastewater spills and (b) risks in relation to inter-aquifer connectivity and an order that the Shenandoah EMP should be referred to the NT EPA for an independent assessment or, in the alternative, an order that varies the Minister’s original decision and establishes conditions in the Shenandoah EMP. On August 25, 2025, the NTCAT granted leave for the substantive proceedings to be withdrawn by the ECNT. This followed the dismissal of the ECNT’s stay application, with the NTCAT handing down its reasons for dismissing the application on November 27, 2024 and the dismissal of the ECNT’s application to issue summonses and admit further expert reports, with the NTCAT handing down its reasons for dismissing the application on July 15, 2025.

On December 6, 2024, Lock the Gate Alliance Ltd (“Lock the Gate”) lodged an Originating Application in the Federal Court of Australia seeking an injunction under s475(2) of the Environment Protection and Biodiversity Conservation Act 1999 (Cth) (“EPBC Act”), to restrain TB1 Operator from conducting the Shenandoah South Pilot Project and a declaration under §21 of the Federal Court of Australia Act 1976 (Cth) that the Shenandoah South Pilot Project is an action which involves unconventional gas development and is likely to have a significant impact on a water resource within the meaning of §§24D and 24E of the EPBC Act (the “Originating Application”). The Originating Application was heard in the Federal Court of Australia from June 23 to 26, and August 14, 2025 before Owens J, who reserved judgment. On June 26, 2026, Owens J delivered judgment in Lock the Gate Alliance Ltd v Tamboran B2 Pty Ltd [2026] FCA 819, finding that Lock the Gate had not established that the Shenandoah South Pilot Project was likely to have a significant impact on a water resource and dismissing the proceedings with costs.

The following Management’s Discussion and Analysis of Financial Condition and Results of Operations (“MD&A”) summarizes the significant factors affecting the operating results, financial condition, liquidity and capital resources, and cash flows of our Company for the years ended June 30, 2026 and 2025. This MD&A should be read in conjunction with, and is qualified in its entirety by, our consolidated financial statements, the accompanying notes to consolidated financial statements and other financial information included in this report. Except for historical information, the matters discussed in this MD&A contain various forward-looking statements that involve risks, uncertainties and assumptions and other important factors and are based upon judgments concerning various factors beyond our control. Our actual results could differ materially from those anticipated in these forward-looking statements as a result of many factors, including those discussed under “Item 1A - Risk Factors” and elsewhere in this report, any of which could cause the Company’s actual results, performance or achievements, or industry results, to differ materially from any future results, performance or achievements expressed or implied by such forward-looking statements. All forward-looking statements speak only as of the date on which they are made. We undertake no obligation to update such statements to reflect events that occur or circumstances that exist after the date on which they are made. Additionally, you should refer to the “Cautionary Note Regarding Forward-Looking Statements.”

Overview

We are an early stage, growth-driven independent natural gas exploration and production company focused on an integrated approach to the commercial development of the natural gas resources in the Beetaloo located within the Northern Territory of Australia. We hold approximately 2.8 million net prospective acres and are the largest acreage holder in the Beetaloo Basin. We intend to continue to develop our resources and regularly review acquisition opportunities that meet our strategic and financial objectives.

We are focused on developing early stage, unconventional gas resources within our portfolio. Our key assets are (i) a 25% non-operated working interest in EP 161, (ii) a 61.25% working interest in EPs 76, 98 and 117, where we are the operator, and (iii) a 100% working interest in EPs 136 and 143, where we are the operator, all of which are located in the Beetaloo. Refer to our working interest following the completion of several transactions in “Items 1 and 2. Business and Properties” for additional information.

Recent Developments

In July 2026, Tamboran completed the stimulation campaign on the SS2-4H, SS2-5H and SS2-3H wells in the Northern Pilot Area. The program was the first three-well zipper stimulation and the largest stimulation campaign conducted in the Beetaloo Basin, with 178 stages placed across approximately 30,000 lateral feet, including ten stages of locally produced Beetaloo Red Sand in the SS2-5H well. The 2026 three well drilling program on the SS1 pad commenced following mobilization of the H&P FlexRig® Flex 3 rig to the SS1 pad with spudding of the first well on July 2, 2026. The SS1-6H and SS1-4H wells have been drilled and cased to total depth with 9,505-foot and 9,329-foot usable lateral sections, respectively, and the SS1-2H well is currently being drilled. Stimulation of the three SS1 wells is planned for the fourth quarter of calendar year 2026.

Practical completion of the SPP occurred on July 17, 2026 and mechanical completion of the SPCF occurred on July 26, 2026. In early September 2026, Tamboran commenced the commissioning of the SPCF, with first gas sales delivered into the Northern Territory gas market on September 5, 2026 from the Company's Shenandoah South 2 pad to the NT Government at a discounted price (75% of the contract price) to the long-term Gas Sales Agreement, reflecting the interruptible nature of supply during commissioning. Two wells are currently delivering unconstrained rates into the market, with the remaining wells to be brought online as required to deliver nominated volumes, and volumes are expected to ramp up to the plateau of 40 TJ/d in accordance with the Northern Territory Government's nominations. Commissioning activities are expected to be completed in the fourth quarter of calendar year 2026.

In early September 2026, Santos, as operator of EP 161 (Tamboran 25%), spudded the Jibera South 1H well with the Ensign 971 rig, the first of a two well appraisal program in the Beetaloo East depocenter. The Jibera South 1H and Newcastle South 1H wells are planned to be drilled with 10,000-foot horizontal sections targeting the Mid Velkerri B Shale and stimulated and flow tested across up to 60 stages per well, with stimulation planned for mid-2027.

In September 2026, Tamboran and Liberty Energy entered into a non-binding Memorandum of Understanding setting out the intent to extend the hydraulic fracture stimulation and wireline services agreement covering Tamboran's Beetaloo Basin operations, under which Liberty Energy intends to begin phasing lower-emissions pumping equipment into the Beetaloo fleet from 2027. See “Items 1 and 2. Business and Properties—Our Business Plan.”

Market Outlook

We believe natural gas can play a key role in supporting the emissions reduction targets of many regional markets through the transition of coal-to-gas fired power plants. To date the increasing global demand for LNG, as well as under-investment in new supply, is expected to lead to LNG supply shortages.

We have the potential, subject to achieving commercial viability in the Beetaloo, to supply natural gas to both Australian domestic and international LNG markets, which would support countries in the region in achieving their GHG emission reduction targets and help reduce global GHG emissions if LNG is adopted as an alternative to coal fired power. We are in the initial phase of development of our operations. Successful commercialization of the Beetaloo will require the development of the infrastructure necessary to conduct our business as planned on commercially acceptable terms. In addition, success of our business will rely on the Australian East Coast and the Asian LNG markets maintaining elevated prices relative to North America to offset the higher costs associated with developing infrastructure in the Beetaloo. The natural gas industry is cyclical and commodity prices are highly volatile. We expect the natural gas markets will continue to be volatile in the future. Our future revenue, profitability and future growth are highly dependent on the prices we will receive for natural gas production. See our risk factor titled “Natural gas prices are volatile. A reduction or sustained decline in prices may adversely affect our business, financial condition or results of operations and our ability to meet our financial commitments or raise capital.”

Global, industry-wide supply chain disruptions have resulted in widespread shortages of labor, materials and services. Such shortages have resulted in our facing significant cost increases for labor, materials and services. Principally, commodity costs for steel and chemicals required for drilling, higher transportation and fuel costs and annual wage increases have increased our operating costs for fiscal years 2025 and 2026. Typically, as the price for natural gas increases, so do associated costs. Conversely, in a period of declining prices, associated cost declines are likely to lag and may not adjust downward in proportion to prices. Some supply chain constraints and inflationary pressures could persist into fiscal year 2027 but are expected to plateau; however, we cannot accurately predict future supply chain constraints and inflation. We cannot predict the future inflation rate but to the extent inflation remains elevated, we may experience cost increases in our operations, including costs for drill rigs, workover rigs, hydraulic fracturing fleets, tubulars and other well equipment, as well as increased labor costs. If we are unable to recover higher costs through higher commodity prices, our future revenue stream would be significantly impacted.

We are taking actions to mitigate supply chain and inflationary pressures. We are monitoring the situation and assessing its impact on our business, including with respect to our partners. For example, we pre-purchased long lead materials including casing and tubulars, chemicals and downhole equipment necessary for our planned development for fiscal year 2027. We have in place a 10-year option, of which six years remain, with H&P to contract for up to four additional FlexRigs®. We are working closely with other suppliers and contractors to ensure availability of supplies on site, especially fuel, steel and chemical supplies which are critical to many of our operations and are working on diversifying suppliers. However, these mitigation efforts may not succeed or be insufficient.

Factors that Affect Comparability of Future Results

Our financial condition and results of operations for the periods presented and future periods may not be comparable, either from period to period or going forward primarily for the following reasons:

Success in our Development of our Natural Gas Properties

Because we have no operating history in the production of natural gas, our future results of operations and financial condition will be directly affected by our ability to develop and commercialize our assets through our drilling programs and future sales and marketing.

Natural Gas Revenue

Through June 30, 2026, we had not generated any revenue from natural gas production due to the stage of our operations, which was appraisal drilling and the final stages of midstream construction. No revenue from natural gas production is reflected in our financial statements as first sales occurred after the period end.

Operating Costs and Expenses

During the fiscal year ended June 30, 2026, natural gas production had not commenced. The initial gas sales in September 2026 should be construed as initial test sales. If and when we do commence natural gas production in quantities to generate regular revenue, we will incur additional operating costs and expenses, workover costs, taxes and royalty fees. Our operating costs and expenses consisted of the following during fiscal years 2026 and 2025: salaries, share based compensation, and related taxes and benefits of personnel employed by us, professional fees for consultants, auditors, tax advisors and legal services, depreciation and amortization of corporate assets, the loss on sale of assets due to the sale of rigs in fiscal year 2025, accretion of asset retirement obligations, exploration expenses, LNG feasibility studies, a Checkerboard fee that was settled in shares of common stock in fiscal year 2025, and general and administrative expenses.

Acquisitions

In fiscal year 2026, the Group completed the acquisition of approximately 98.1% of the issued and outstanding equity interests of Falcon Australia and all of the issued and outstanding equity interests of (i) Falcon Hungary, (ii) Falcon Ireland, (iii) Falcon Holdings and (iv) Falcon South Africa.

We may continue to grow our operations and financial results through strategic accretive acquisition opportunities that may arise relevant to our Beetaloo strategy. We regularly review acquisition opportunities and intend to pursue acquisitions that meet our strategic and financial targets. Additionally, we may from time to time effect divestitures of certain of our non-core assets.

Supply, Demand, Market Risk and the Impact on Natural Gas Prices

As discussed above in “Market Outlook,” the natural gas industry historically has been cyclical with highly volatile commodity prices. Natural gas prices are subject to large fluctuations in response to relatively minor changes in the demand for natural gas. Prices are affected by current and expected supply and demand dynamics, including the market disruptions resulting from the Russia-Ukraine war, the Iran-United States war and the broader Middle East conflict, the changing U.S. regulatory environment and trade and tariffs policies, the Australian domestic gas market reservation policy, supply growth driven by advances in drilling and completion technologies, resulting in increased supply in the global market. Other factors impacting supply and demand include weather conditions (including severe weather events), pipeline capacity constraints, inventory storage levels, basis differentials, export capacity, supply chain quality and availability, as well as other factors, the majority of which are outside of our control. These commodity prices are likely to remain volatile in the future. Sustained periods of low natural gas prices could materially and adversely affect our financial condition, our results of operations, the quantities of natural gas that we can economically produce and our ability to access capital. These key factors will only affect us when we produce and sell natural gas.

Results of Operations

Our functional currency is the Australian dollar, and our reporting currency is the U.S. dollar. For revenues and expenses reported in any period, we use the average currency exchange rate between U.S. dollars and Australian dollars for the period. For assets and liabilities, we use the current currency exchange rate as at the end of the period, based on the same source. Given the fluctuations in currency exchange rates, we may experience changes in reported amounts from period to period that occur primarily as a result of these fluctuations and that are not reflective of actual changes in our business or operations.

Currently, we are exposed to foreign exchange risk, particularly with the U.S. dollar and Australian dollar, as a result of revenue and expenses that are denominated in each currency. It is our policy to limit the use of financial derivatives and seek risk mitigation through natural hedges. These natural hedges include the maintenance of U.S. dollar and Australian bank accounts and deposits. Because our functional currency is the Australian dollar, our reported financial results are subject to fluctuation resulting from changes in the U.S. dollar to Australian dollar exchange rate.

The following tables present selected financial information for the periods presented:

Fiscal Years Ended June 30, 2026 and June 30, 2025

Revenue and other operating income. The commissioning phase of the Pilot Project commenced in September 2026 (subsequent to fiscal year 2026). Therefore, we did not realize any revenue and other operating income during fiscal years 2026 and 2025, respectively.

Compensation and benefits, including stock-based compensation. Compensation and benefits, including stock based compensation, increased by $3.1 million during fiscal year 2026, as compared to fiscal year 2025 largely due to period on period increase in headcount, the transition to a calendar year employee bonus schedule, and compensation awarded to the interim and new CEO.

Consultancy, legal and professional fees. Consultancy, legal and professional fees remained fairly consistent period-over-period.

Loss on remeasurement of assets classified as held for sale. Tamboran recognized a loss on assets classified as held for sale amounting to $0.4 million during fiscal year 2025 primarily due to the write down of rig 403 to the fair value less costs to sell. Tamboran disposed of all assets held for sale in fiscal year 2025.

Accretion of asset retirement obligations expense. For fiscal year 2026, an expense for accretion of asset retirement obligations of $1.2 million was recognized. The recognition of such an expense was primarily due to the accretion of asset retirement obligation liabilities in relation to all EPs, inclusive of EPs 76, 98, 117, 136 and 161, as well as the SPCF pad.

Exploration expense. Exploration expense decreased by $0.8 million during fiscal year 2026, as compared to fiscal year 2025, as the prior period had increased activity for topographical, geographical and geophysical studies and other indirect expenditures while the current period had increased indirect expenditure related to our non-operated permits while the operated permits focused on the flow test for SS2-1H and preparation of the stimulation programs of SS2-4H, SS2-5H, and SS2-3H, the costs of which are capitalized.

Camp expense recoveries, net. During the year ended June 30, 2026, expenses for the field camp of $2.5 million were recognized primarily related to camp utilization, camp services, and related consumables. These costs are offset by recoveries from external parties who utilize the camp.

LNG feasibility study expense. In fiscal year 2025, the Group incurred expenses of $6.0 million related to certain studies and pre-front-end engineering and design services related to the NTLNG facility. These studies were substantially completed in fiscal year 2025, therefore, the expense related to these studies was de minimis in fiscal year 2026.

Checkerboard fee. For fiscal year 2025, the Group incurred an expense of $6.0 million related to the satisfaction of certain payment obligations to DWE under the TB1 Joint Venture Agreement. This obligation was satisfied through the issuance of common stock, subsequent to shareholder approval received in November 2024. No such expense was incurred in fiscal year 2026.

General and administrative. General and administrative costs increased by $0.9 million during fiscal year 2026, as compared to fiscal year 2025, primarily as a result of increased expenses related to insurance, headcount, travel, and other office and administrative fees.

Interest Income, net. Interest income, net increased by $1.1 million during fiscal year 2026, as compared to fiscal year 2025, primarily due to interest received from cash at bank and term deposits during the period.

Foreign currency translation. In fiscal year 2026, we recognized a foreign currency translation gain of $11.9 million, primarily due to the strengthening of the Australian Dollar as of June 30, 2026 in comparison to the average rate during the fiscal year 2026. In fiscal year 2025, we recognized a foreign currency translation gain of $2.8 million, primarily due to the strengthening of the Australian Dollar as of June 30, 2025 in comparison to the average rate during the period. Foreign exchange gains and losses resulting from the settlement of foreign currency transactions and from the translation at fiscal year-end exchange rates of monetary assets and liabilities denominated in foreign currencies are recognized on our income statement.

Income Tax Expense. We have no income tax expense primarily due to operating losses incurred for fiscal years 2026 and 2025. We have provided a full valuation allowance on our net deferred tax asset because management has determined that it is more likely than not that we will not earn sufficient income to realize the deferred tax assets during a foreseeable future period. Management will continue to assess the potential for realizing deferred tax assets based upon income forecast data and the feasibility of future tax planning strategies and may record adjustments to the valuation allowance against deferred tax assets in future periods, as appropriate, that could have a material impact on the statement of operations.

Liquidity and Capital Resources

We are an exploration and appraisal stage enterprise and will continue to be so until commencement of substantial production from our natural gas properties. We do not expect to generate any substantial revenue from production until early calendar year 2027, at the earliest, which will depend upon successful drilling results, completion of commissioning of the gas processing facility, additional and timely capital funding, and access to suitable infrastructure. Until then our primary sources of liquidity are expected to be cash on hand and funds from future private and public equity placements, debt funding and asset sales.

We expect to incur substantial expenses and generate significant operating losses as we continue to develop our natural gas prospects and as we:

• complete our current appraisal drilling, testing program and SPCF commissioning;
• develop and commercialize our assets, including development of pipelines, the proposed NTLNG facility and other infrastructure;
• opportunistically invest in additional natural gas assets adjacent to our current positions; and
• incur expenses related to operating as a public company and compliance with regulatory requirements.

Our future financial condition and liquidity will be impacted by, among other factors, the success of our exploration and appraisal drilling program, the number of commercially viable natural gas discoveries made, the quantities of natural gas discovered, the speed with which we can bring such discoveries to production, and the actual cost of exploration, our ability to identify and complete acquisition opportunities and appraisal and development of our prospects.

For the fiscal year ending June 30, 2027, we estimate that we will need to invest approximately $113.3 million to progress our Pilot Project development plans. We expect cash on hand and available funds from the committed undrawn portion of the SPCF debt facility to be sufficient to fund the stimulation and tie-in costs of the SS2-3H, SS2-4H and SS2-5H wells (completed in July and August 2026 ahead of production start-up), drilling and stimulation costs of SS1-6H, SS1-4H and SS1-2H for production tie-in during 2027, long leads for further production wells and committed SPCF construction costs. We may seek additional funding through asset sales or public or private financings. Additional funding may not be available to us on acceptable terms or at all. In addition, the terms of any financing may adversely affect the holdings or the rights of our stockholders. For example, if we raise additional funds by issuing additional equity securities, further dilution to our existing stockholders will result. If we are unable to obtain funding on a timely basis, we may be required to significantly curtail one or more of our planned activities. We also could be required to seek funds through arrangements with collaborators or others that may require us to relinquish rights to some of our assets which we would otherwise develop on our own, or with a majority working interest.

Cash and Cash Equivalents

The following table summarizes our key measures of liquidity for the periods indicated (in thousands).

As of June 30, 2026, we had $219.1 million in cash and cash equivalents. This balance represents an increase of $179.7 million from June 30, 2025, as a result of proceeds from cash calls, capital raising activities and the Syndicated Facility Agreement offset by consideration paid for the Falcon Acquisition and spending related to operations on the SS2-5H, SS2-3H and SS2-1H pilot wells, construction of the SPCF and other corporate expenditures in the fiscal period.

Capital Commitments

We had the following five-year capital commitments as of June 30, 2026 and June 30, 2025 which are not recognized as liabilities or payable in the consolidated statement of financial position (all dollar amounts are presented in thousands):

Sweetpea Commitments

As of June 30, 2026, Sweetpea committed to spend $24.0 million related to two licenses, EP 136 with total commitments of $14.5 million and EP 143 with total commitments of $9.6 million.

A renewal application for EP 136 was submitted to the Department of Mining and Energy (“DME”) in November 2025, requesting an extension of the permit for a period of 18 months to January 2031. DME replied in July 2026 and agreed to a permit extension only through July 2030. As such, the Group maintains a minimum work program commitment of $14.5 million.

An application for EP 143 was submitted and approved by the DME in June 2026 requesting a variation of the minimum work program for years 2 and 3. The total minimum work program commitments remained the same at $9.6 million

EP 161

For the EP 161 working interest, we are obligated to contribute our share of expenses to uphold our stake in this permit, for which Santos Limited is the operator. An application was approved in December 2025 to extend the term of the exploration permit and the required work program which includes the drilling and stimulation of two horizontal wells, along with related geological and geophysical studies to March 2027. Our commitment through March 2027 is expected to be $6.0 million based on the minimum work requirements. There are no minimum commitment requirements after March 2027.

Beetaloo Joint Venture

A variation application was submitted to DME in September 2025 to vary the minimum work program for years 3, 4 and 5. Refer to Note 17 for further details. These commitments include an expected spend of $73.3 million related to drilling and multi-stage hydraulic fracturing of four wells, 3D seismic survey, and subsurface studies, with expenditure across EP 76 of $14.1 million, EP 98 of $43.7 million and EP 117 of $15.5 million.

Midstream

As of June 30, 2026, the Group had contractual commitments of approximately $23.0 million relating to the remaining construction and commissioning of the SPCF project, compared to $9.1 million as of June 30, 2025. As of June 30, 2026, construction of the facility was approximately 90% complete and overall project completion was approximately 93%. Given the advanced stage of the project, substantially all of the remaining forecast expenditure required to complete the facility has been contracted and is reflected in the contractual commitment amount above. The $13.9 million increase from the prior year principally reflects the contracting during fiscal year 2026 of the entirety of the commissioning phase and remaining construction, which had not been contracted as of June 30, 2025. All of the committed amount is expected to be settled within six months of the balance sheet date.

Cash Flows

The following table summarizes our cash flows for the periods indicated (in thousands):

Net Cash Used in Operating Activities

For fiscal year 2026, net cash used in operating activities was $34.6 million during which we incurred a net loss of $30.5 million, compared to net cash used in operating activities for fiscal year 2025 of $29.6 million, during which we incurred a net loss of $39.6 million. The net loss for fiscal year 2026 included the non-cash impacts of depreciation and amortization, stock-based compensation, performance bond facility fees, accretion of asset retirement obligations, interest expense and foreign exchange differences. Additionally, in the year ended June 30, 2026, net unfavorable changes in operating assets and liabilities totaled $12.5 million, primarily consisting of an $8.3 million decrease in accounts payable and accrued expenses due to timing of our pay cycle during the fiscal period, and a $7.8 million increase in prepaid expenses and other assets, partially offset by a $2.9 million decrease in trade and other receivables.

Net Cash Used in Investing Activities

For fiscal year 2026, net cash used in investing activities was $187.6 million compared to $98.8 million for fiscal year 2025. In the current period there was spend on exploration and evaluation activities of $112.0 million in connection with the drilling of the SS2-5H, SS2-3H and SS2-1H pilot wells, $37.3 million of spend related to SPCF, $0.4 million of spend related to sand mining, $3.4 million related to interest on financing lease liabilities, $5.0 million related to interest on borrowings under our Syndicated Facility Agreement, $12.1 million in connection with the Falcon Acquisition and $17.4 million related to the assignment of a note receivable, partially offset by the receipt of the R&D tax incentive of $0.1 million.

Net Cash from Financing Activities

For fiscal year 2026, net cash received from financing activities was $412.3 million compared to $101.1 million received for fiscal year 2025. This increase was primarily due to $291.0 million in net proceeds from the issue of shares in connection with the Company’s capital raises in fiscal year 2026 in comparison to net proceeds of $42.9 million received in fiscal year 2025. Other activity in the fiscal year 2026 included $74.5 million attributable to contributions from noncontrolling interest holders to fund their share of cash calls compared to $61.5 million in the prior period, $58.9 million of proceeds from the Syndicated Facility, payment of debt issuance costs of $3.6 million, repayments of finance lease liabilities of $8.2 million and $0.3 million related to the payment of performance bond facility establishment fees.

Critical Accounting Estimates

Management’s discussion and analysis of our financial condition and results of operations are based upon our consolidated financial statements, which have been prepared in accordance with GAAP. The preparation of our financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the reported amounts of certain assets, liabilities and related disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The following critical accounting policies relate to the more significant estimates and assumptions used in preparing the consolidated financial statements.

Accounting for Natural Gas Properties

We are in the exploration stage and have not yet realized any revenues from our operations. We group our EPs into areas of interest according to geographical and geological attributes. We use the successful efforts method of accounting for expenditure incurred in each area of interest. Under this method, all general exploration and evaluation costs such as geological and geophysical costs are expensed as incurred. The direct costs of acquiring the rights to explore, drilling exploratory wells and evaluating the results of drilling are capitalized as exploration and evaluation assets (as a part of unproved properties) pending the determination of the success of the well. If a well does not result in a successful discovery, the previously capitalized costs are immediately expensed.

Impairment of Natural Gas Properties

Where an indicator of impairment exists for an unproved property and it is determined that future appraisal drilling or development activities are unlikely to occur, an impairment expense is recorded. The impairment loss shall be measured as the amount by which the carrying amount of a long-lived asset (or asset group) exceeds its fair value. Upon approval of the commercial development of a project, the exploration and evaluation asset is classified as a development asset. Once production commences, development assets are transferred to property, plant and equipment and are depleted using the unit-of-production method based upon estimates of proved developed reserves.

Joint Interest Activities

Some of the Group’s exploration, development and production activities are conducted jointly with other entities whereby each party holds an undivided interest in each asset and is proportionately liable for each liability in the scope of such arrangement. The Group has recognized its proportionate share of assets, liabilities, revenues and expenses in respect of such arrangements. These have been incorporated in the consolidated financial statements under the appropriate classifications.

Asset Retirement Obligations

Our asset retirement obligations (“AROs”) consist primarily of estimated future costs associated with the plugging, dismantling, removal, site reclamation and similar activities of natural gas properties in accordance with the requirements of respective EPs and with applicable local, state and federal laws. The discounted fair value of an ARO liability is required to be recognized in the period in which it is incurred, with the associated asset retirement cost capitalized as part of the carrying cost of the related long-lived asset. The recognition of an ARO requires numerous assumptions to be made by management regarding such factors as the estimated probabilities, amounts and timing of settlements; the credit-adjusted risk-free rate to be used; inflation rates; and future advances in technology. In periods subsequent to the initial measurement of the ARO, we recognize period-to-period changes in the liability resulting from the passage of time and revisions to either the timing or the amount of the original estimate of undiscounted cash flows. Increases in the ARO liability due to passage of time impact net income as accretion expense. The related capitalized cost, including revisions thereto, is charged to expense through depreciation and amortization over the life of the related asset.

Litigation and Environmental Contingencies

In the ordinary course of business, we are and may at times be subject to claims and legal actions. Management does not believe the impact of such matters will have a material adverse effect on our financial position or results of operations. We are subject to extensive federal, state, and local environmental laws and regulations, which may materially affect our operations. These laws, which are constantly changing, regulate the discharge of materials into the environment and may require us to remediate, remove or mitigate the environmental effects of the disposal or release of petroleum or chemical substances at various sites.

In our acquisition of existing assets, we may not be aware of what environmental safeguards were taken during the time such assets were operated or the environmental liabilities associated with such assets.

We maintain comprehensive insurance coverage that we believe is adequate to mitigate the risk of any adverse financial effects associated with these risks. However, should it be determined that a liability exists with respect to any environmental cleanup, remediation, or restoration, the liability to cure such a violation could still fall upon us. No claim has been made, nor are we aware of any liability which we may have, as it relates to any material environmental cleanup, remediation, restoration, or the material violation of any rules or regulations relating thereto.

Environmental expenditures are expensed or capitalized depending on their future economic benefit. Those related to an existing condition caused by past operations and that have no future economic benefits are expensed as incurred. Liabilities for expenditures of a noncapital nature are recorded when environmental assessment and/or remediation is probable, and the cost can be reasonably estimated.

Income Taxes

Income taxes are accounted for under the asset-and-liability method. Deferred tax assets and liabilities occur when differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating loss and tax credit carryforwards exist and are recognized for future tax consequences. 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 and carryforwards 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 includes the enactment date. Current income tax recognized in the profit or loss is the tax payable or receivable on taxable income calculated using applicable income tax rates enacted as at reporting date. Current tax liabilities or assets are measured at the amounts expected to be paid or recovered from the relevant tax authority.

In assessing the probability that a deferred tax asset will be realized management considers whether it is more likely than not that all or some portion of the deferred tax assets will not be realized. We provide valuation allowances against deferred tax assets that are not considered more likely than not to be realized. The valuation of the deferred tax asset is dependent on, among other things, our ability to generate a sufficient level of future taxable income. In estimating future taxable income, we consider both positive and negative evidence in our assessment. If our estimate of future taxable income or tax strategies changes at any time in the future, we would record an adjustment to our valuation allowance. Recording such an adjustment could have a material effect on our financial condition or results of operations.

Deferred income tax relating to timing differences and unused tax losses are only recognized to the extent that it is probable that future tax profit will be available against which the benefits of the deferred tax asset can be utilized.

Stock-Based Compensation

We measure and recognize compensation expense related to our share-based compensation based on the estimated fair value of the awards. The fair value of the award is measured at the grant date and is recognized as an expense over the course of the award’s vesting period. The fair value of the stock options granted is estimated using either the Black-Scholes (for awards that vest based on service conditions), Binomial Lattice or the Monte-Carlo option-pricing model (for awards that vest based on market conditions). Each of these models includes the share price at grant date, exercise price, the term of the right, expected price volatility of the underlying share, the expected dividend yield and the risk-free interest rate for the term of the right. The Monte Carlo model also incorporates a probability-based value impact of the market condition.

Recent Accounting Pronouncements

See “Note 2—Summary of Significant Accounting Policies” to our consolidated financial statements included elsewhere in this report for more information about recent accounting pronouncements, the timing of their adoption, and our assessment, to the extent we have made one, of their potential impact on our financial condition and our results of operations.

Inherent Limitations on Effectiveness of Controls

A control system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance that the control system’s objectives will be met. Because of its inherent limitations, internal control over financial reporting may not prevent or detect all control issues or misstatements. Accordingly, our controls and procedures are designed to provide reasonable, not absolute, assurance that the objectives of our control system are met. Projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Evaluation of Disclosure Controls and Procedures

During the fiscal period covered by this report, our management, with the participation of the Chief Executive Officer and Chief Financial Officer, carried out an evaluation of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Exchange Act) as of June 30, 2026. Based on such evaluation, our Chief Executive Officer and Chief Financial Officer have concluded that, as a result of the material weakness in internal control over financial reporting described below, our disclosure controls and procedures were not effective as of June 30, 2026. In light of the material weakness in the Company’s internal control over financial reporting described below, we performed additional analysis and other procedures to ensure that our consolidated financial statements were prepared in accordance with GAAP. Accordingly, our management, including the Chief Executive Officer and Chief Financial Officer, has concluded that the consolidated financial statements included in this Annual Report on Form 10-K fairly present, in all material respects, our financial position, results of operations, and cash flows as of and for the periods presented, in accordance with GAAP.

In connection with the preparation of our financial statements for the fiscal years ended June 30, 2026 and 2025, we identified deficiencies in our internal control over financial reporting, which in the aggregate, constituted a material weakness as of June 30, 2026 and 2025, respectively. The deficiencies, which continue to exist, and, in the aggregate, constituted a material weakness as of June 30, 2026, were identified in connection with the preparation of our financial statements for the fiscal year ended June 30 2026, as described below. Certain deficiencies identified in prior periods as described under “Consideration of Previously Identified Deficiencies” below have been deemed to no longer contribute to the material weakness as of June 30, 2026. The deficiencies that continue to exist as of June 30, 2026, which in the aggregate constitute a material weakness, relate to insufficiently designed and operating internal control over financial reporting and consist of the following:

i) The Company failed to effectively document management review procedures to validate the completeness and accuracy of transactions and to clearly define and evidence processes used and criteria and judgment applied in performance of critical business processes.

ii) The Company failed to fully resolve identified segregation of duties conflicts with system access for designated business and IT privileged users; thus related user access and application change management procedures could not be relied upon for select Company systems.

These deficiencies, while relating to different aspects of the Company's internal control environment, are interrelated as the deficiencies affect both the reliability of information used in the financial reporting process and the effectiveness of controls designed to identify potential errors in that information. As a result, management concluded that the deficiencies should be evaluated on an aggregate basis and, collectively, constitute a material weakness in internal control over financial reporting.

Management’s Annual Report on Internal Control over Financial Reporting

Management is responsible for establishing and maintaining adequate internal controls over our financial reporting, as defined in Rule 13a-15(f) under the Exchange Act. Tamboran’s internal controls over financial reporting are processes designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with GAAP. Due to their inherent limitations, internal controls over financial reporting may not be effective in preventing or detecting misstatements. Additionally, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate due to changes in conditions or that the degree of compliance with policies or procedures may deteriorate.

Management evaluated the effectiveness of Tamboran’s internal controls over financial reporting as of June 30, 2026, based upon the Internal Control-Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO - 2013”). Based on the assessment using these criteria, Management concluded that, as of June 30, 2026, our internal controls over financial reporting were ineffective to detect a material misstatement due to deficiencies that existed in the design or operation of our internal controls over financial reporting that are considered to be a material weakness as described herein above. 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 the company’s annual or interim financial statements will not be prevented or detected on a timely basis.

Notwithstanding the existence of this material weakness in our internal controls over financial reporting, Management believes that Tamboran’s consolidated financial statements fairly present in all material respects the

Company’s financial condition, results of operations, and cash flows for the periods presented. We continue to evaluate the effectiveness of internal controls and procedures on an on-going basis.

As Tamboran continues to be an emerging growth company, this report does not include an attestation report from our independent registered public accounting firm regarding internal controls over financial reporting.

Remediation Plan for the Material Weakness

In response to the material weakness identified and described above, our management, with the oversight of the Audit & Risk Management Committee of our board of directors, will continue to dedicate significant efforts and resources to further improve our control environment and to take steps to remediate the remaining deficiencies aggregating to the material weakness.

With respect to management review procedures, during fiscal year 2025, we engaged an internal audit firm to assist with the documentation of our processes and internal controls. We continue to provide training to control owners, supported by external consultants, as appropriate, in support of an effective internal control framework, including how to sufficiently document and evidence the operation of internal controls. We will continue to hire accounting and finance personnel, or engage technical specialists, who possess the required technical knowledge to ensure reporting requirements are met and segregation of duties are maintained, and procedures for determining, communicating, implementing, and monitoring controls over the period-end financial close and reporting processes are formally documented.

With respect to segregation of duties within our information technology systems, we have restricted administrator access in certain systems and are implementing mitigating controls where restriction is not practicable. We are also implementing a formal segregation of duties review process across our in-scope systems and are updating our change management policy and related documentation requirements.

The material weakness cannot be considered remediated until the newly designed control activity operates for a sufficient period of time and management has concluded, through testing, that the control is operating effectively.

Consideration of Previously Identified Deficiencies

The following deficiencies were previously disclosed as components of our material weakness in our Annual Report on Form 10-K for the year ended June 30, 2025:

i. lack of manage access and manage change IT general controls over our cloud-based enterprise resource planning system.

ii. accounting for complex transactions in accordance with GAAP.

We have concluded that these deficiencies no longer individually or in the aggregate rise to the level of a material weakness as of June 30, 2026. Specifically, we have:

i. Transitioned core financial and operational transactions from the legacy enterprise resource planning system to an enterprise system that is governed by third party security and data handling controls in fiscal year 2025 and formalized design and execution of mitigating activities in fiscal year 2026.

ii. Implemented processes supporting documented technical accounting analysis and review of non-routine and complex transactions, with support from external specialists, where appropriate.

Changes in Internal Control Over Financial Reporting

Other than described above, there were no changes in the Company’s internal control over financial reporting (as defined in Rule 13a-15(f) and Rule 15d-15(f) under the Exchange Act) during the fiscal year ended June 30, 2026 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.