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 and our working interest partners have exploration permits (“EPs”) to approximately 4.7 million contiguous gross acres (approximately 1.9 million net acres to Tamboran) and are currently the largest acreage holder in the Beetaloo. We believe natural gas will play a significant role in the transition to cleaner energy and are committed to supporting the global energy transition by developing commercial production of natural gas in the Beetaloo with net zero equity Scope 1 and 2 emissions. The Beetaloo, located approximately 300 miles southeast of the city of Darwin in the Northern Territory of Australia, covers approximately seven million acres (approximately 10,800 square miles) of outback and is believed to contain significant quantities of unconventional natural gas resources. To date, more than $600 million has been invested by various public and private companies in the exploration, appraisal and development of the Beetaloo. Based on data from our appraisal wells, we believe the most productive sections of the Beetaloo to be those at greater than 6,000-foot vertical depth. Initial data suggests that these sections demonstrate the highest productivity and reservoir pressures and exhibit the lowest decline rates in the Beetaloo. To date, our appraisal and development activities have focused on the dry gas shale target of the Middle Velkerri B formation, although we expect to eventually evaluate other benches for future development. Regional data from exploration wells, initial results from our appraisal wells, including well log and core data, as well as available 2-D seismic data, indicate that the geological properties of the Middle Velkerri section in the Beetaloo are widespread and contiguous across an area encompassing approximately 610,400 acres (approximately 950 square miles) and that the Beetaloo has geology similar to that of the Marcellus Shale of the Appalachian Basin in the northeastern United States (the “Marcellus”). In particular, the dry gas areas of the Marcellus qualify as an appropriate analogous reservoir to the Middle Velkerri shale of the Beetaloo, having similar rock and fluid properties (such as organic-rich source rock and similar thermal maturity), similar reservoir conditions (including depth, pressure gradient and temperature ranges), and drive mechanism (using pressure depletion and gas desorption). While the Marcellus is at a more advanced stage of development than the Beetaloo, we believe comparison to the Marcellus may assist in our estimations and interpretation of data. We have participated in six appraisal wells over the last three fiscal years, four of which we drilled as the operator: Exploration Tamboran Well Name Operator Non-Operator(s) Permit Date Drilled Working Interest Tanumbirini #2 (“T2H”) Santos Tamboran 161 May 2021 25 % Tanumbirini #3 (“T3H”) Santos Tamboran 161 August 2021 25 % Maverick 1V (“M1V”) Tamboran N/A 136 August 2022 100 % Amungee NW-2H (“A2H”) Tamboran DWE & FOG 98 November 2022 38.75 % Shenandoah South 1H (“SS1H”) Tamboran DWE & FOG 117 August 2023 38.75 % Amungee NW 3H (“A3H”) Tamboran DWE & FOG 98 September 2023 38.75 % --- SS1H delivered an average 30-day initial production (“IP30”) flow rate of 3.2 MMcf/d over the 1,644-foot, 10-stage stimulated length within the Middle Velkerri B Shale, a 60-day initial production (“IP60”) flow rate of 3.0 MMcf/d, and a 90-day initial production (“IP90”) flow rate of 2.9 MMcf/d. Normalizing the production rate for a 10,000-foot horizontal lateral, the IP30 flow rate in SS1H would have been approximately 19.5 MMcf/d, the IP60 flow rate would have been approximately 18.4 MMcf/d, and the IP90 flow rate would have been approximately 17.8 MMcf/d. Flow test results from the two wells in which we participated on a non-operated basis, the T2H and T3H, delivered IP30 rates of 2.1 MMcf/d and 3.1 MMcf/d, respectively, over approximately 2,200-foot and 2,000-foot horizontal sections. Normalizing those production rates to our optimal development plan of 10,000-foothorizontal sections, we expect the IP30 rates in T2H and T3H would have been approximately 9.5 MMcf/d and 15.5 MMcf/d, respectively. To date, 21 wells have been drilled in the Beetaloo intersecting the Middle Velkerri shales. Of those wells we have participated in the drilling of seven wells, though we consider only the six drilled in the last three fiscal years to be our appraisal wells (“our wells”). The remaining 14 wells drilled to date in the Beetaloo were drilled by third parties. None of the wells drilled in the Beetaloo to date are currently flowing to sales. Four of our wells (SS1H, T2H, T3H, and A2H) are horizontal wells that have been stimulated, flow tested, and produced natural gas to the surface in test volumes. Based on the initial flow rates of our wells, we believe only SS1H is currently a productive well, meaning it is capable of producing sufficient quantities of gas to justify completion. We believe T2H, T3H, and A2H will likely be capable of producing sufficient quantities of gas to justify completion or recompletion at a future date with further investment and workover. No flow test information is currently available for M1V and A3H, so at this time we do not have sufficient data to determine whether these wells are capable of producing sufficient quantities of gas to justify completion or recompletion. T2H and T3H were drilled with low intensity, shorter lateral lengths (approximately 2,000 feet), while SS1H and A3H were drilled with Helmerich & Payne International Holdings, LLC’s (“H&P”) modern US FlexRig® that was imported into Australia in 2023 and will increase spacing between well pads. In our next phase of drilling and completion, we anticipate increasing frac stages by extending the horizontal length of our wells. Our contiguous acreage position and the scarcity of other operators or urban areas near the Beetaloo will provide us with the space necessary to eventually drill pad wells with up to three to four-mile horizontal laterals, greatly increasing efficiencies and production from a relatively smaller number of wells. We have experienced geologic complexity similar to that of U.S. shale basins in our drilling activities to date, and based on our experience and seismic data, we believe such complexity to be generally characteristic of the Beetaloo. We believe the relative lack of complexity in the geology of the Beetaloo will enable us to achieve more predictable well recoveries and permit greater lateral lengths. Our key assets are (i) a 25% non-operated working interest in EP 161, (ii) a 38.75% working interest in EP 76, 98 and 117, where we are the operator, and (iii) a 100% working interest in EPs 136, 143 and EP(A) 197, where we are the operator, all of which are located in the Beetaloo. We have an undivided 50% interest in EPs covering four million gross (1.5 million net) acres through TB1, EPs 76, 98 and 117. We hold our rights in the Beetaloo through EPs granted by the government of the Northern Territory for initial periods of five years with a right to renew twice for additional five-year periods, and with a further right to extend the term with Ministerial approval based upon approval of a work program. An EP grants the holder the exclusive right to explore for petroleum and to carry on such operations and execute such works as are necessary for that purpose, in the exploration permit area. We are also entitled to apply for a retention license in areas where petroleum has been identified but commercial viability is yet to be established. Retention licenses are for a term of five years and may be renewed without a statutory limitation. A retention license would provide us with the exclusive right to carry on in the license area geological, geophysical, and geochemical programs and other operations and works, including appraisal drilling, as reasonably necessary to evaluate the prospective resources in the license area. Upon commercialization of the natural gas properties subject to an EP or retention licenses, we are eligible to apply to convert relevant productive areas of our EPs (or any future retention licenses) into production licenses with an initial term of either 21 or 25 years as determined by the Northern Territory Minister for Environment (the “Minister”), which can be further renewed. A production license grants a party or parties exclusive rights to explore for petroleum and recover it from the license area and to carry out such operations and execute such works in the license area as are necessary for the exploration for and recovery of petroleum. We will be required to pay a statutory royalty to the Northern Territory Government (“NT Government”) of 10% of the gross value, at the well-head, of all petroleum produced in connection with a production license or EP in a project area. The gross value of that petroleum is determined by the Petroleum Royalty Act (NT). Additionally, we will pay royalties of between 6% to 11% to other third parties under certain commercial arrangements. Headquartered in Sydney, Australia, we have been investing in the development of Australian oil and natural gas reserves since our formation in 2009. Since 2014, we have focused our development activities within the Northern Territory. We were incorporated in the State of Delaware on October 3, 2023 for the purposes of effecting the corporate reorganization. Our principal executive offices are located at Suite 01, Level 39, Tower One, International Towers Sydney, 100 Barangaroo Avenue, Barangaroo NSW 2000, Australia.
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