Tamboran (NYSE: TBN) secures $198M funding, targets 3Q 2026 first gas
Filing Impact
Filing Sentiment
Form Type
8-K
Rhea-AI Filing Summary
Tamboran Resources Corporation reported operational progress and financing updates for the quarter ended March 31, 2026. The company highlighted a farm-out of about 10,000 acres to Daly Waters Energy for a carry of up to US$28.5 million across its Pilot Area and Beetaloo Central Development Area, helping fund development without direct equity dilution from that transaction.
The Shenandoah South 6H well delivered a record average IP20 flow rate of 10.3 MMcf/d, supporting the quality of Tamboran’s Beetaloo West acreage. Construction of the Sturt Plateau Compression Facility was 88% complete at the end of April 2026 and remains on budget, with commissioning targeted in 3Q 2026.
The balance sheet was strengthened through a US$31 million PIPE transaction and an April 2026 capital raise of about US$188 million (net of fees). Tamboran reported cash of US$95 million and net drawn debt of US$23 million as of March 31, 2026, and cited pro forma cash of about US$298 million to fund planned 2026–2027 drilling and stimulation programs aimed at delivering first gas and further resource delineation in the Beetaloo Basin.
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Insights
Tamboran advances Beetaloo development while fortifying its funding base.
Tamboran Resources is progressing from appraisal toward initial production in Australia’s Beetaloo Basin. A record IP20 flow rate of 10.3 MMcf/d from the SS‑6H well indicates competitive well performance and supports the commercial potential of its Mid Velkerri B Shale acreage.
Midstream readiness is improving, with the Sturt Plateau Compression Facility reported as 88% complete and on its P50 budget and schedule, targeting commissioning in 3Q 2026. This aligns infrastructure timing with Tamboran’s plan for first gas sales from the Shenandoah South Pilot Project.
On the funding side, the company closed a US$31 million PIPE and raised about US$188 million net via a public and entitlement offer, leading to pro forma cash of roughly US$298 million. Management indicates this capital should support planned drilling and stimulation through 2027–2028, reducing near-term financing risk as the resource is further delineated.
8-K Event Classification
2 items: 2.02, 9.01
2 items
Item 2.02
Results of Operations and Financial Condition
Financial
Disclosure of earnings results, typically an earnings press release or preliminary financials.
Item 9.01
Financial Statements and Exhibits
Exhibits
Financial statements, pro forma financial information, and exhibit attachments filed with this report.
Key Figures
Farm-out carry: US$28.5 million
PIPE transaction: US$31 million
April 2026 capital raise: US$188 million
+8 more
11 metrics
Farm-out carry
US$28.5 million
Carry across Pilot Area and BCDA farmed to Daly Waters Energy
PIPE transaction
US$31 million
Net proceeds from January 2026 PIPE
April 2026 capital raise
US$188 million
Net proceeds from public and entitlement offers
Pro forma cash
US$298 million
Including US$95 million cash at March 31, 2026 and near-term inflows
Cash balance
US$95 million
Cash as of March 31, 2026 including restricted share
Net drawn debt
US$23 million
Debt drawn for SPCF construction as of March 31, 2026
Undrawn debt capacity
US$39 million
Remaining facility capacity for SPCF completion
Average East Coast gas price
US$9.20 per mcf
Average contracted price for 2027 supply reported by ACCC
Henry Hub comparison
US$3.56 per MMBtu
Henry Hub price versus East Coast gas for July–December 2025
SS-6H IP20 rate
10.3 MMcf/d
Record 20-day average initial production from Mid Velkerri B Shale
SPCF completion status
88%
Construction completion at end of April 2026
Key Terms
IP20, PIPE transaction, farm-out, Sturt Plateau Compression Facility (SPCF), +2 more
6 terms
IP20 financial
"delivered a record average 20‑day initial production (IP20) flow rate of 10.3 million cubic feet per day"
PIPE transaction financial
"Tamboran shareholders voted to approve a US$31 million Private Investment in Public Equity (PIPE) transaction"
A PIPE transaction is when a publicly traded company sells new shares or convertible securities directly to a select group of private investors, rather than through a public offering. It’s essentially a quick way for a company to raise cash, but it can dilute existing shareholders and often involves a price discount, so investors watch PIPEs for their potential impact on share value and ownership stakes—like a private top-up that changes the size of everyone’s slice of the pie.
farm-out financial
"farm down approximately 10,000 acres of its working interest across the Pilot Area and the Beetaloo Central Development Area (BCDA) to Daly Waters Energy"
A farm-out is an agreement where the owner of exploration or production rights lets another company take over some drilling or development work in exchange for covering costs and receiving a share of future production or revenue. Think of it like hiring a partner to finish and pay for a risky construction project in return for a slice of the rent; it reduces the original owner’s expense and risk while allowing investors to judge how much future output and costs will change.
Sturt Plateau Compression Facility (SPCF) technical
"The Sturt Plateau Compression Facility (SPCF) was 88% complete at the end of April 2026"
Beetaloo Basin technical
"execute our Beetaloo Basin strategy"
forward-looking statements regulatory
"This press release contains “forward-looking” statements related to the Company"
Forward-looking statements are predictions or plans that companies share about what they expect to happen in the future, like estimating sales or profits. They matter because they help investors understand a company's outlook, but since they are based on guesses and assumptions, they can sometimes be wrong.
` NYSE: TBN, ASX: TBN 3Q FY26 Result Presentation Mr. Todd Abbott – Chief Executive Officer North America: May 13, 2026 | Australia: May 14, 2026
The information in this presentation includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), which include statements on Tamboran Resources Corporation's ("we", "us" or the "Company") opinions, expectations, beliefs, plans objectives, assumptions or projections regarding future events or future results. All statements, other than statements of historical fact included in this presentation regarding our strategy, present and future operations, financial position, estimated revenues and losses, projected costs, estimated reserves, prospects, plans and objectives of management are forward-looking statements. When used in this presentation, words such as “may,” “assume,” “forecast,” “could,” “should,” “will,” “plan,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “project,” “budget”, "achieve," "progress," "target," "expand," "deliver“, "potential," "propose," "enter," "provide," "contribute," and similar expressions are used to identify forward-looking statements, although not all forward-looking statements contain such identifying words. These forward-looking statements are based on management’s current belief, based on currently available information, as to the outcome and timing of future events at the time such statement was made. These forward‐looking statements are not a guarantee of our performance, and you should not place undue reliance on such statements. Forward looking statements may include statements about, among other things: our business strategy and the successful implementation of our business strategy; our future reserves; our financial strategy, liquidity and capital required for our development programs; estimated natural gas prices; our dividend policy; the timing and amount of future production of natural gas; our drilling and production plans; competition and government regulation; our ability to obtain and retain permits and governmental approvals; legal, regulatory or environmental matters; marketing of natural gas; business or leasehold acquisitions and integration of acquired businesses; our ability to develop our properties; the availability and cost of developing appropriate infrastructure around and transportation to our properties; the availability and cost of drilling rigs, production equipment, supplies, personnel and oilfield services; costs of developing our properties and of conducting our operations; our ability to reach FID and execute and complete our planned pipeline or planned LNG export projects; our anticipated Scope 1, Scope 2 and Scope 3 emissions from our businesses and our plans to offset our Scope 1, Scope 2 and Scope 3 emissions from our business; our ESG strategy and initiatives, including those relating to the generation and marketing of environmental attributes or new products seeking to benefit from ESG related activities; general economic conditions, including cost inflation; credit markets and the ability to obtain future financing on commercially acceptable terms; our ability to expand our business, including through the recruitment and retention of skilled personnel; our dependence on our key management personnel; our future operating results; and our plans, objectives, expectations and intentions. Except as otherwise required by applicable law, we disclaim any duty to update any forward-looking statements, all of which are expressly qualified by the statements in this section, to reflect events or circumstances after the date of this presentation. Tamboran is subject to known and unknown risks, many of which are beyond the ability of Tamboran to control or predict. These risks may include, for example, movements in oil and gas prices, risks associated with the development and operation of the acreage, exchange rate fluctuations, an inability to obtain funding on acceptable terms or at all, loss of key personnel, an inability to obtain appropriate licenses, permits and or/or other approvals, inaccuracies in resource estimates, share market risks and changes in general economic conditions. Such risks may affect actual and future results of Tamboran and its securities. Maps and diagrams contained in this presentation are provided to assist with the identification and description of Tamboran’s interests. The maps and diagrams may not be drawn to scale. This presentation includes market data and other statistical information from third party sources, including independent industry publications, government publications or other published independent sources. Although we believe these third-party sources are reliable as of their respective dates, we have not independently verified the accuracy or completeness of this information. The industry in which we operate is subject to a high degree of uncertainty and risk due to a variety of factors, which could cause our results to differ materially from those expressed in these third-party publications. Numbers in this report have been rounded. As a result, some figures may differ insignificantly due to rounding and totals reported may differ insignificantly from arithmetic addition of the rounded numbers. All currency amounts are represented as USD unless otherwise stated (AUD/USD exchange rate of 0.65). This presentation does not purport to be all inclusive or to necessarily contain all the information that you may need or desire to perform your analysis. In all cases, you should conduct your own investigation and analysis of the data set forth in this presentation, and should rely solely on your own judgment, review and analysis in evaluating this presentation. This presentation contains trademarks, tradenames and servicemarks of other companies that are the property of their respective owners. We do not intend our use or display of other companies’ trademarks, tradenames and servicemarks to imply relationships with, or endorsement or sponsorship of us by, these other companies. This presentation was approved and authorised for release by Todd Abbott, the Chief Executive Officer of Tamboran Resources Corporation. Disclaimer 2
3 Tamboran Resources Corporation (NYSE: TBN, ASX: TBN) 3Q FY26 highlights Agreed farm-out of ~10,000 acres to DWE, providing a US$28.5 million carry across the Pilot Area and BCDA acreage at similar economic terms to the INPEX/DWE transaction SPCF construction currently 88% complete and progressing on P50 time and budget. The APA-owned SPP undergoing final commissioning ahead of tie-in to SPCF Upcoming two well program in Santos-operated EP 161 acreage to delineate additional resources in the Beetaloo East depocenter Preparing to commence 2026 Beetaloo Basin program with stimulation at least three wells (SS- 3H, -4H & -5H) and drilling of at least two wells (SS-7H & -8H) Balance sheet materially strengthened with ~US$219 million capital raise and PIPE transaction (net of fees), supporting optionality for increase in gas sales and delineation of resources Pro forma cash balance of ~US$298 million, including cash balance of US$95 million at March 31, 2026(1) and near-term inflows of US$203 million(2) 1 2 4 3 5 6 (1) Reported cash balance of US$101.9 million less Daly Waters Infrastructure, LP 50% share of restricted cash. (2) Near term cash inflows include US$15 million from acreage sale to DWE (announced May 2025) and US$188 million (net of fees) from April 2026 public offer and entitlement issue.
2026 catalysts Planning most active year in the Beetaloo Basin | First gas sales from the Beetaloo Basin on track for 3Q 2026 4Note: Timing of upcoming catalysts is indicative, and subject to change in the event of unforeseen events and key stakeholder and Joint Venture approvals. Refer to disclaimer on Slide 2. 3Q 2025 Secured debt facility to fund processing infrastructure, backstopped by the Northern Territory Government 3Q 2025 Reached Final Investment Decision for the SS Pilot Project 4Q 2025 Successfully drilled SS-4H, 5H, 6H and stimulated the SS-6H well 1Q 2026 Announced farmout of BCDA acreage and Pilot Area to DWE (alongside DWE’s transaction with INPEX) 1Q 2026 Received court approval to complete Falcon acquisition 2Q 2026 Delivered record peak IP20 flow rate for SS-6H well test 1H 2026 Stimulate the SS-3H, -4H and -5H wells prior to first sale 1H 2026 Drill the SS-7H and -8H wells in DWE-operated Southern Pilot Area 2H 2026 Progress Orion Area joint venture opportunities 3Q 2026 First gas sales from the SS Pilot Project to Northern Territory 3Q 2026 Participate in the Jibera South 1H and Newcastle South 1H wells with Santos-operated in EP 161 Newcastle Jibera NORTHERN TERRITORY Ep 161 Orion Area BCDA 6H, 5H, 4H 2HST1, 3H 7H, 8H Kilometers 0 20 40
Q&A
6 Strategic farmout of BCDA with Daly Waters Energy Recognizes a value premium on Tamboran’s core Beetaloo position 1. Clear value marker for Tamboran’s acreage from Japan’s largest E&P − Farmout of ~10,000 net acres across the Northern and Southern Pilot Areas and BCDA recognizes the value uplift of Tamboran’s core Beetaloo position, with implied acreage value well above recent transactions 2. Non-dilutive capital to support Tamboran’s strategic development initiatives − Staged earn-in for up to ~US$28.5 million via well carries accelerates development while preserving balance sheet strength 3. Validation of Tamboran’s pathway to commercialization of Beetaloo − Transaction follows DWE’s strategic JV with INPEX, operator of Ichthys LNG, reinforcing third-party confidence in the Beetaloo Basin and supporting Tamboran’s commercialization pathway Transaction summary Phase 1 – Pilot Area Phase 2 – BCDA (Election) Total Pre-transaction Working Interest 50.0% 12.5% Working interest farmed down 5.625% 2.500% Net acres 2,277 7,877 10,154 Carry commitment (US$ million) 11.6 11.6 23.2 Additional milestone carry (US$ million)(1) - 5.3 5.3 (1) Subject to DWE electing to progress to Phase 2 of the Farmout Agreement. NORTHERN TERRITORY NT Ichthys LNG Pilot Area BCDA Kilometers 0 10 20 Amadeus
Sturt Plateau Compression Facility construction 88% complete and within P50 budget and schedule 7 SPCF construction activities (April 2026) − The SPCF project remains within P50 budget and schedule − 88% complete at end April 2026 − Electrical work 64% and pipeline connection 55% complete − Funding up to the P90 cost estimate of the SPCF is supported by US$118 million (gross to JV) facility with a consortium of lenders (announced September 2025) − Financing facility guaranteed by the NTG for Tamboran’s 50% share of the debt facility (up to A$75 million) − US$46 million (gross to JV) drawn from facility at March 31, 2026, with US$77 million undrawn − On track to commence commissioning in 3Q 2026 − During commissioning period, Tamboran will sell gas for 75% of the contract price
EP 161 upcoming activity Santos stating Beetaloo Basin gas as LNG backfill for GLNG and DLNG in the early 2030s | Targeting FID by mid-2029 8 − Santos (ASX: STO) planning two 10,000-foot horizontal well, Jibera South 1H and Newcastle South 1H in EP 161 (Tamboran 25% non-operator) in 2026 − Ensign Rig 971 contracted and to be mobilized to the Beetaloo Basin for 3Q 2026 drilling operations − Both wells planning to be stimulated with up to 60 stages − Planned to be flow tested over 12-month period − Targeting resource delineation in the Beetaloo East depocenter, supported by data points from Mt Brown (formerly Tanumbirini) (2021) and Maverick (2022) − Santos evaluating backfill opportunities for DLNG (North) and GLNG (East) and already progressing pipeline approvals − Targeting FID in late 2028 or early 2029, targeting first backfill gas by 2033 (as per operator) Mt Brown
9 Tamboran’s funding pathway Funding allows Tamboran to further delineate activities across the Beetaloo East depocenter for future partnerships and development Uses of funds Activity Existing Funding Deliver initial gas sales from SS Pilot Project ✓ SPCF infrastructure funded from syndicated debt facility ✓ Drilling two Commitment Wells with DWE in Southern Pilot Area ✓ Complete Falcon acquisition ✓ Progress key approvals for future large-scale development ✓ Fund Tamboran’s share of BCDA activity being farmed out to DWE (alongside DWE/INPEX farmout) ~US$198 million of capital raised in April 2026 funds 2026 and 2027 growth and appraisal activities(2) Increase production above ~40 MMcf/d into NT gas market Participation in two EP 161 wells with Santos in the Beetaloo East acreage(1) Potential for ongoing funding of Orion Area subject to successful farmout Tamboran funded through to 2028 (1) Based on the current approved work program under EP 161. (2) Tamboran successfully raised ~US$198 million from the April 2026 capital raise to fund these activities, additional funding applied toward projects beyond these initiatives, subject tot Board approval.
95 298 (13) (21)(2) 91 31 6(3) 1(4) 15 188(5) U S $ m il li o n 3Q FY26 Change in Cash Balance Strengthened balance sheet following recent capital raise 10 (1) Restricted cash of US$13.8 million (US$6.9 million net to Tamboran) to be used for future interest payments and commitment fees relating to the SPCF syndicated debt facility. (2) Cash flow from investing includes cash associated with drilling activity and infrastructure; Cash flow from investing adjusted for receivables relating to cash calls due from JV partners and DWE’s share of restricted cash. (3) TBN share of debt proceeds drawn. (4) Includes lease payments and FX adjustments. (5) Capital raise amount less fees. Total cash and expected near-term inflows of ~US$298 million at March 31, 2026 − Cash and expected near term cash inflows of ~US$298 million at March 31, 2026(1) − Drawn debt of US$23 million to fund construction of the SPCF, with undrawn debt of US$39 million at March 31, 2026 − In April 2026, completed Public Offer raising US$188 million (net of fees) − In January 2026, Tamboran shareholders approved the US$31 million PIPE transaction (net of fees) − Progressing research and development tax rebates, which if successful, will provide incremental near-term cash inflows − Balance sheet expected to support activities beyond first gas sales, with further appraisal drilling and resource delineation across the Beetaloo East and West through 2027
Aus + PNG 89 31% Middle East 78 28% Rest of the World 116 41% 11 Asia needs the stability of Australian LNG Disrupted Middle East production underscores the importance of Australia’s stable LNG supply to Asia. New sources of supply are needed to fill Australian LNG facilities. Supplier of Asian LNG Demand (MTPA) 2024 283 mt UAE: 15–16 days Australia / PNG: 6–9 days US East: 24 days (via Panama), 38 days (via Cape) Mexico: 10–14 days Canada: 10 days LNG Shipping Duration to North Asia(2) Source: Woodmac, Company Estimates, IGU World LNG Report – 2025 Edition. (1) Middle East represents Oman, Qatar and UAE. (2) Kpler – platform for global trade intelligence. Estimated shipping duration to Futtsu Japan at a vessel speed of 17 knots. November 2023. (3) Assumes 10% debottlenecking potential is realized, excludes permitted expansion. Declining LNG Facility Capacity Usage (Eastern and Northern Aus, excluding expansion) (3) 1 32 1 3 2 Australia has been reliably supplying Asia since 1989. In 2024, Australia and Papua New Guinea contributed 31% to Asian LNG demand Australia is well located to meet growing energy demand forecasts in Asia. Proximity to market allows for lower transport costs, lower emissions and shorter timeframes compared to alternate supply routes Ullage is growing in East and North Australian LNG as existing Australian LNG gas feedstock depletes into the 2030s. Australian LNG facilities are expected to be underutilized which the Beetaloo is well positioned to capitalize on At Risk Supply Stable Supply Bcf/d New source of gas needed (1) 4.4 3.0 0.6 2.5 5.0 5.5 2027 2037 Utilised Ullage Potential Expansion
- 0.2 0.4 0.6 0.8 1.0 1.2 2026 2028 2030 2032 2034 2036 2038 2040 2042 2044 V o lu m e ( B c f/ d ) Australian Southern State Supply/Demand Balance(1) Existing and Committed Supply Anticipated Supply Flow from North Daily Average Demand 12 (1) Source: Australian Energy Market Operator (AEMO) 2026 Gas Statement of Opportunities (March 26, 2026), p.72. (2) Source: Australian Energy Market Operator (AEMO) 2026 Gas Statement of Opportunities (March 26, 2026), p.79. LNG export capacity of 25.3 MTPA + 10% for fuel. Excludes Uncertain Supply. Emerging LNG ullage within the 25.3 MTPA of LNG projects in Queensland, Australia Favorable East Coast gas market dynamics Emerging shortfall on Australia’s East Coast of ~1.2 Bcf/d from 2035 due to declining local production Shortfall opportunity for Beetaloo Basin gas - 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 2026 2028 2030 2032 2034 2036 2038 2040 2042 2044 V o lu m e ( B c f/ d ) Ullage available at Gladstone LNG facilities(2) LNG Exporters' Committed Supply LNG Exporters' Anticipated Supply LNG Exporters' Domestic Third Party Gas LNG Export Capacity Ullage available for Beetaloo Basin gas via LNG at Gladstone Limited northern supply and pipeline capacity to meet southern market demand
13 Phase 2 – East Coast domestic gas price ~US$9.20 per mcf average contracted price for East Coast producers in 2027 | >158% higher than Henry Hub − Majority of gas volumes on Australia’s East Coast are contracted business-to-business, with limited spot market − AEMO has reported a shift away from commodity-linked GSAs towards fixed-price GSAs in recent years − Higher prices reflect lack of investment in new domestic gas supply and longer transport route to market − Pricing confidential, however the ACCC releases gas offer and bid ranges throughout the year − In March 2026, the ACCC announced average contracted East Coast price of ~US$9.20 per mcf between July and December 2025 for supply in 2027, a ~158% premium to Henry Hub pricing during that period 8.84 8.33 9.20 9.44 10.09 9.45 - 2 4 6 8 10 12 Jan - Jun 2025 Jul - Sept 2025 Oct - Dec 2025 Jan - Jun 2025 Jul - Sept 2025 Oct - Dec 2025 G a s P ri c e ( U S $ p e r m c f) Agreed gas prices to the East Coast market for 2027 supply(1) Producer Range Retailer Range US$ per MMBtu Jul – Dec’25 ACCC Reported Producer Offers(1) 9.20 Henry Hub(2) 3.56 Australian East Coast gas premium 158% (1) Source: ACCC Gas Inquiry (2017 – 2030): Interim Update on East Coast gas market – March 2026 (p.19). (2) Bloomberg (between July 1, 2025 and December 31, 2025).
Glossary AEMO Australian Energy Market Operator AGP Amadeus Gas Pipeline APA APA Group (ASX: APA) APLNG Australia Pacific LNG BCDA Beetaloo Central Development Area (TBN 10% interest) Bcf Billion Cubic Feet BJV Beetaloo Joint Venture (TBN, DWE and Falcon Oil & Gas Australia Limited) Bpm Barrels per minute CDI Chess Depositary Interest (200 CDIs = 1 NYSE Common Stock) CSG Coal Seam Gas DWE Daly Waters Energy, LP (Daly Waters Energy, LP are 100% owned by Formentera Australia Fund, LP, which is managed by Formentera Partners, LP, a private equity firm of which Bryan Sheffield serves as managing partner) EP Exploration Permit EPC Engineering, Procurement and Construction FEED Front End Engineering Design FID Final Investment Decision ft Feet GSA Gas Sales Agreement H&P Helmerich & Payne 14 IP90 Average production rate over the first 90 days of production JV Joint Venture LNG Liquefied Natural Gas MTPA Million tonnes per annum MMcf/d Million cubic feet per day NT Northern Territory NTH Native Title Holders PJ Petajoule PL Production Licence SS Shenandoah South SPCF Sturt Plateau Compression Facility SPP Sturt Plateau Pipeline TBN Tamboran Resources Corporation TD Total Depth TJ/d Terajoule per day
Tamboran Resources Corporation ARBN 672 879 024 Tower One, International Towers Suite 1, Level 39, 100 Barangaroo Avenue, Barangaroo NSW 2000, Australia +61 2 8330 6626 www.tamboran.com Third quarter activities report for period ended March 31, 2026 Highlights • In March 2026, Tamboran announced the Company would farm down approximately 10,000 acres of its working interest across the Pilot Area and the Beetaloo Central Development Area (BCDA) to Daly Waters Energy, LP (DWE) for a US$28.5 million carry, subject to structured off-ramp provisions. • In April 2026, the Beetaloo Joint Venture (BJV) delivered a record average 20‑day initial production (IP20) flow rate of 10.3 million cubic feet per day (MMcf/d) from the Shenandoah South 6H (SS‑6H) well. • The Sturt Plateau Compression Facility (SPCF) was 88% complete at the end of April 2026. The SPCF construction remains on budget and on track to commence commissioning in 3Q 2026. The Sturt Plateau Pipeline (SPP) is undergoing final commissioning activities ahead of tie-in to the SPCF. • The 2026 Beetaloo Basin program is expected to commence imminently with the stimulation of the SS-3H, -4H and -5H wells on the SS2 pad. The BJV is also planning to commence drilling activities of the SS-7H and -8H wells on the SS1 pad in mid-2026 using the Helmerich & Payne (NYSE: HP) FlexRig® Flex 3 rig. • In January 2026, Tamboran shareholders voted to approve a US$31 million Private Investment in Public Equity (PIPE) transaction (net of fees). The PIPE transaction was completed in January 2026 and was supported by Mr. Bryan Sheffield, Tamboran’s Board and management, and existing shareholders. • In April 2026, Tamboran raised US$188 million (net of fees) via a US$119 million public offer (before fees) at US$35.00 per share of Common Stock, US$61 million via an Institutional Entitlement Offer and US$18 million via a partially underwritten Retail Entitlement Offer. • As of March 31, 2026, the Company had a cash balance of US$95 million (including Tamboran’s 50% share of restricted cash) and net drawn debt of US$23 million associated with the construction of the SPCF. Total undrawn debt of US$39 million remained for the completion of the SPCF (net Tamboran). • Following the completion of the April 2026 capital raise, Tamboran has a pro forma cash of US$298 million and is funded for the proposed 2026 and 2027 programs to deliver first gas and delineate gas resources across the Beetaloo West and East acreage. Tamboran Resources Corporation Chief Executive Officer, Todd Abbott, said: “The March 2026 quarter represents another major step forward for Tamboran as we continue to execute our Beetaloo Basin strategy. “We delivered record flow results from SS-6H well, which further demonstrates the high quality of our acreage position in the Beetaloo West. While the recently announced farmout to DWE, in conjunction with the DWE farmout to INPEX, provides a capital‑efficient pathway to progress the Pilot Area and BCDA. ANNOUNCEMENT May 13, 2026 Tamboran Resources Corporation (NYSE: TBN; ASX: TBN)
2 “Following the successful completion of our PIPE in January 2026 and the April 2026 capital raise, we are well funded to execute our 2026 and 2027 programs. This positions us to deliver first gas during 3Q 2026 and accelerate material resource delineation across our core Beetaloo West and East acreage positions over the next 18 months. “We are actively preparing to commence our 2026 Beetaloo Basin program, which is expected to include drilling of at least four wells and stimulation of at least five wells. Importantly, the stimulation program is expected to test local sand across numerous stages of the stimulation of the SS-4H well, which, if successful, could have significant implications for the reduction in costs going forward. “With a strengthened balance sheet, high‑quality acreage and a clear line of sight to near‑term catalysts, we believe Tamboran is well positioned to continue advancing one of Australia’s most significant onshore gas resources.” Shenandoah South Pilot Project Tamboran 47.5 per cent working interest in 20,309 acres and operator of the Northern Pilot Area(1) In April 2026, Tamboran announced record IP20 flow rates from the SS-6H well rate of 10.3 MMcf/d from the Mid Velkerri B Shale. The flow test was concluded in April 2026, with the well delivering a stable rate of 8.8 MMcf/d at a flowing wellhead pressure of approximately 580 psi. At the conclusion of the flow test, water was continuing to unload at a rate of ~270 bbl/d, indicating the well was still in the process of cleaning up. Construction of the SPCF, a 50/50 joint venture with Daly Waters Infrastructure (DWI), continued during the quarter with strong progress made on the electrical, instrumentation and controls, and piping, despite disruptions caused by wet weather. At the end of the period, ~64% of cable pulls and 55% of the piping installation was complete. The SPCF construction project remains within the P50 risked schedule and budget despite the significant weather events in the region during the wet season. The SPCF construction cost is being funded via the SPCF syndicated debt facility, which was announced on September 30, 2025. The project remains on track to deliver first commissioning gas sales during Q3 2026, subject to global economic conditions. Tamboran and DWI have completed a Concept Select study for the expansion of the SPCF. The BJV is evaluating the study and reviewing options available with the proposed expansion. Tamboran 38.75 per cent working interest in 20,309 acres and non-operator of the Southern Pilot Area(2) During the quarter, Tamboran and DWE continued to progress the two well drilling program on SS1 well pad in the DWE-operated Southern Pilot Area. The two commitment wells are planned to be drilled with 10,000-foot horizontal 1 Subject to the completion of the SS-2H ST1 and SS-3H wells on the Shenandoah South pad 2. Tamboran expects to increase ownership of the proposed Northern Pilot Area to 50% following completion of the acquisition of Falcon Oil & Gas Ltd. and the proposed acreage swap with Daly Waters Energy, LP. Tamboran’s interest is expected to be 44.375% following the completion of the farm-down to DWE. 2 Tamboran expects to increase ownership of the proposed Southern Pilot Area to 50% following completion of the acquisition of Falcon Oil & Gas Ltd. and the proposed acreage swap with Daly Waters Energy, LP. Tamboran’s interest is expected to be 44.375% following the completion of the farm-down to DWE.
3 sections targeting the Mid Velkerri B Shale as backfill wells to maintain plateau production of ~40 MMcf/d under the Northern Territory Government Gas Sales Agreement. Drilling remains on track to commence during 2Q 2026 using the Helmerich & Payne (H&P) super-spec FlexRig® Flex 3 Rig. The wells are planned to be stimulated using the Liberty frac fleet during 2H 2026. EP 161 Santos 75 per cent working interest and operator, Tamboran 25 per cent working interest During the March 2026 quarter, the operator of the EP 161 permit, Santos, undertook upgrades to the Ensign 971 rig ahead of drilling activity planned for 3Q 2026. The Jibera South 1H and Newcastle South 1H wells are planned to be drilled with 10,000-foot (~3,000-metre) horizontal sections targeting the Mid Velkerri B Shale. Both wells are planned to be stimulated and flow tested across up to 60 stages per well. Regulatory assessment of the Environment Management Plan (EMP) and Well Operations Management Plan (WOMP) continued during the quarter, with the operator receiving an approved WOMP April 2026 and EMP in May 2026. Santos continues to assess potential pipeline routes to connect its Beetaloo Basin acreage to Darwin and East Coast market. EP 136, EP 143 and EP(A) 197 Tamboran 100 per cent working interest and operator During the quarter, Tamboran continued to progress approvals, and conducted an on-country meeting with Native Title Holders in preparation for the acquisition of a 2D seismic survey in 2027 on EP 143. On April 30, 2026, Sweetpea Petroleum Pty Ltd. withdrew its application for onshore petroleum exploration permit EP(A) 197 with the Department of Mining and Energy. Recent evaluation of the permit has resulted in Tamboran concluding that the acreage is non-core and outside the prospective net acreage position within the Beetaloo depocenter. Commercial and Corporate Farm-down of BCDA acreage to Daly Waters Energy, LP During the quarter, Tamboran and Formentera Partners (Formentera), the owner of DWE, executed a Farm-in Agreement (Farm-in Agreement) to advance development of the Beetaloo Basin in Australia’s Northern Territory. Under the Farm-in Agreement, Tamboran will farm-down approximately 10,000 acres of its working interest across the Pilot Area and the BCDA to DWE. The Farm-in Agreement provides for a staged earn-in, up to ~US$28.5 million, subject to structured off-ramp provisions. The transaction follows DWE announcing a strategic joint venture with INPEX Corporation, Japan’s largest E&P and operator of the 8.9 MTPA (~1.2 Bcf/d) Ichthys LNG facility in Darwin.
4 Completed Public Offer to raise US$188 million (net of fees) In April 2026, Tamboran raised US$103 million (A$147.1 million) of gross proceeds via a registered underwritten public offer at an offer price of US$35.00 per share of Common Stock. The underwriters exercised their option to purchase an additional 443,491 shares of Common Stock at the Public Offer price, raising an additional US$15.5 million (A$22.1 million). In conjunction with the public offer, the Company completed an institutional component of the 1 for 10 pro rata accelerated non-renounceable entitlement offer (ANREO). The institutional component was supported by new and existing institutional shareholders, raising US$61.4 million (A$87.7 million) at the same price as the public offer, or A$0.25 per new CHESS Depository Interests (CDIs). The partially underwritten retail component of the ANREO was completed in late April 2026 raising a further US$17.9 million (A$24.8 million). RBC Capital Markets (RBC) and E&P Capital Pty Limited (E&P) are acting as joint lead managers and bookrunners for the Entitlement Offer. Bookrunners, BofA Securities and Scotiabank, along with co-managers Johnson Rice & Company LLC, Piper Sandler, Pickering Energy Partners and Northland Capital Markets. Proposed acquisition of Falcon Oil & Gas Ltd (Falcon) During the quarter, shareholders of both Falcon Oil & Gas Ltd. and Tamboran approved Tamboran’s proposed transaction to acquire all the subsidiaries of Falcon, subject to certain regulatory approvals. In March 2026, the Supreme Court of British Columbia approved the transaction, subject to certain amendments to the Plan of Arrangement relating to the treatment of Falcon shareholders that are subject to sanctions. Tamboran and Falcon have agreed to extend the Plan of Arrangement until June 30, 2026.
5 Capital Structure At the end of the quarter, Tamboran had total cash on hand of US$95 million (excluding US$6.9 million of DWE’s net share of restricted cash). Total of US$23 million (net) in drawn debt, with US$39 million undrawn. The current capital structure, as at the date of this report, is as follows: 20,313,460 Common Stock 1,601,089,800 CHESS Depositary Interests 200:1 (equivalent to 8,005,449 Common Stock) 28,318,909 Total equivalent Common Stock (5,663,781,800 equivalent CDIs at 200:1) 18,151,222 CDI Options fully vested (unlisted) 35,850,000 CDI Options unvested and subject to milestones (unlisted) 793,894 Restricted Stock Units Changes to the capital structure from the previous quarter include: • Issuance of 2,956,602 Common Stock (591,320,400 CDI equivalent) as part of the public offering. • Issuance of 443,491 Common Stock (88,698,200 CDI equivalent) to underwriter of the greenshoe option as part of the public offering. • Issuance of 148,308,400 CDIs (741,542 Common Stock equivalent) as part of the institutional component of the public offering. • Issuance of 1,013,110 Common Stock (202,622,000 CDI equivalent) as part of the retail component of the public offering. • Issuance of 99,375,000 CDI’s (496,875 Common Stock equivalent) as part of the retail component of the public offering. • Issuance of 25,271 Common Stock to Board and Management under the RSU incentives. • Issuance of 2,505 Common Stock to Board and Management under the RSU incentives • Issuance of 1,524,377 Common Stock from the completion of the PIPE transaction. • 65,320 Restricted Stock Units awarded to incoming CEO under the employee incentive scheme • 728,574 Restricted Stock Units awarded to employees under the employee incentive scheme.
6 Permits At the end of the quarter, Tamboran and its subsidiaries held the following prospective acreage positions: Permits Gross Prospective Acres Interest Net Prospective Acres Northern Pilot Area 20,239 44.38%*,(1),(2),(3) 8,982 Southern Pilot Area 20,230 44.38%(1),(2),(3) 8,978 Orion Area 493,229 78.00%*,(1),(2) 384,719 Beetaloo Central Development Area (BCDA) 316,131 10.00%*,(1),(2),(3) 31,613 Retention Lease (RL) 10 218,176 92.00%*,(1),(2) 200,722 North Beetaloo 536,669 100.00%* 536,669 Southeast Beetaloo 914,839 100.00%* 914,839 Northwest Beetaloo 813,460 22.50% 183,029 Southern Development Area 281,633 12.50%(1),(2) 35,204 South Beetaloo 525,740 22.50% 118,292 Northeast Beetaloo 202,931 22.50% 45,659 EP 161 512,000 25.00% 128,000 EP 136 207,000 100.00%* 207,000 Total 5,062,277 2,803,705 *Denotes operator. Note: All working interests are subject to the completion of the acquisition of all the subsidiaries of Falcon Oil & Gas Ltd, which was approved by Tamboran and Falcon shareholders in March 2026 and approval from the Supreme Court of British Columbia, subject to certain amendments to the Plan of Arrangement relating to the treatment of Falcon shareholders that are subject to sanctions. (1) Working interests include impact of the Acreage Sale to Daly Waters Energy, LP, announced in May 2025 and subject to completion of certain conditions precedent. (2) Working interest include impact of Acreage Realignment Agreement with Daly Waters Energy LP. announced in November 2025. (3) Working interests include impact of the farmout to Daly Waters Energy, LP. announced in March 2026. Announcements This Quarterly Activities Report contains information reported in the following announcements released during and subsequent to the reporting period: January 06, 2026 Falcon Oil & Gas Australia Limited approve sale to Tamboran January 12, 2026 Appointment of Mr. Todd Abbott as Chief Executive Officer March 27, 2026 Court approves Tamboran's acquisition of Falcon March 31, 2026 Tamboran farmout Pilot Area and BCDA acreage April 02, 2026 SS-6H Delivers Record IP20 Flow Result April 08, 2026 Entitlement Offer Press Release April 08, 2026 Public Offering of Common Stock
7 April 08, 2026 Pricing of Public Offering April 08, 2026 Launch of Equity Raise April 09, 2026 Completion of US Offer and Institutional Entitlement Offer This announcement was approved and authorised for release by Todd Abbott, the Chief Executive Officer of Tamboran Resources Corporation. For further information, please contact: Investor enquiries: Chris Morbey, Vice President – Corporate Development and Investor Relations +61 2 8330 6626 Investors@tamboran.com Media enquiries: +61 2 8330 6626 Media@tamboran.com About Tamboran Resources Corporation Tamboran Resources Corporation (NYSE/ASX: TBN) is a 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 Basin located within the Northern Territory of Australia. Through its subsidiaries, Tamboran holds approximately 1.9 million net prospective acres and is the largest acreage holder in the Beetaloo Basin.
8 Figure 1: Tamboran’s Beetaloo Basin asset location map. Note: Working interests and proposed permit boundaries on the map are subject to the completion of the acquisition of Falcon Oil & Gas Ltd., the proposed acreage swap with Daly Waters Energy, LP and the farm-down transaction to Daly Waters Energy, LP.
9 Disclaimer Tamboran makes no representation, assurance or guarantee as to the accuracy or likelihood of fulfilment of any forward-looking statement or any outcomes expressed or implied in any forward-looking statement. The forward- looking statements in this report reflect expectations held at the date of this document. Except as required by applicable law or the ASX Listing Rules, Tamboran disclaims any obligation or undertaking to publicly update any forward-looking statements, or discussion of future financial prospects, whether as a result of new information or of future events. The information contained in this announcement does not take into account the investment objectives, financial situation or particular needs of any recipient and is not financial product advice. Before making an investment decision, recipients of this announcement should consider their own needs and situation and, if necessary, seek independent professional advice. To the maximum extent permitted by law, Tamboran and its officers, employees, agents and advisers give no warranty, representation or guarantee as to the accuracy, completeness or reliability of the information contained in this presentation. Further, none of Tamboran nor its officers, employees, agents or advisers accept, to the extent permitted by law, responsibility for any loss, claim, damages, costs or expenses arising out of, or in connection with, the information contained in this announcement. Note on Forward-Looking Statements This press release contains “forward-looking” statements related to the Company within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”) and Section 27A of the Securities Act of 1933, as amended. Forward-looking statements reflect the Company’s current expectations and projections about future events at the time, and thus involve uncertainty and risk. The words “believe,” “expect,” “anticipate,” “will,” “could,” “would,” “should,” “may,” “plan,” “estimate,” “intend,” “predict,” “potential,” “continue,” “participate,” “progress,” “conduct” and the negatives of these words and other similar expressions generally identify forward-looking statements. It is possible that the Company’s future financial performance may differ from expectations due to a variety of factors, including but not limited to: our early stage of development with no material revenue expected until 2026 and our limited operating history; the substantial additional capital required for our business plan, which we may be unable to raise on acceptable terms; our strategy to deliver natural gas to the Australian East Coast and select Asian markets being contingent upon constructing additional pipeline capacity, which may not be secured; the absence of proved reserves and the risk that our drilling may not yield natural gas in commercial quantities or quality; the speculative nature of drilling activities, which involve significant costs and may not result in discoveries or additions to our future production or reserves; the challenges associated with importing U.S. practices and technology to the Northern Territory, which could affect our operations and growth due to limited local experience; the critical need for timely access to appropriate equipment and infrastructure, which may impact our market access and business plan execution; the operational complexities and inherent risks of drilling, completions, workover, and hydraulic fracturing operations that could adversely affect our business; the volatility of natural gas prices and its potential adverse effect on our financial condition and operations; the risks of construction delays, cost overruns, and negative effects on our financial and operational performance associated with midstream projects; the potential fundamental impact on our business if our assessments of the Beetaloo are materially inaccurate; the concentration of all our assets and operations in the Beetaloo, making us susceptible to region-specific risks; the substantial doubt raised by our recurring operational losses, negative cash flows, and cumulative net losses about our ability to continue as a going concern; complex laws and regulations that could affect our operational costs and feasibility or lead to significant liabilities; community opposition that could result in costly delays and impede our ability to obtain necessary government
10 approvals; exploration and development activities in the Beetaloo that may lead to legal disputes, operational disruptions, and reputational damage due to native title and heritage issues; the requirement to produce natural gas on a Scope 1 net zero basis upon commencement of commercial production, with internal goals for operational net zero, which may increase our production costs; the increased attention to ESG matters and environmental conservation measures that could adversely impact our business operations; risks related to our corporate structure; risks related to our common stock and CDIs; and the other risk factors discussed in the this report and the Company’s filings with the Securities and Exchange Commission. It is not possible to foresee or identify all such factors. Any forward-looking statements in this document are based on certain assumptions and analyses made by the Company in light of its experience and perception of historical trends, current conditions, expected future developments, and other factors it believes are appropriate in the circumstances. Forward-looking statements are not a guarantee of future performance and actual results or developments may differ materially from expectations. While the Company continually reviews trends and uncertainties affecting the Company’s results of operations and financial condition, the Company does not assume any obligation to update or supplement any particular forward-looking statements contained in this document.
FAQ
What key operational milestone did Tamboran Resources (TBN) report for 3Q FY26?
Tamboran reported a record IP20 flow rate of 10.3 MMcf/d from the Shenandoah South 6H well. This 20‑day average production rate from the Mid Velkerri B Shale supports the productivity of its Beetaloo West acreage and underpins its pilot development plans.
How much capital did Tamboran Resources (TBN) raise in early 2026?
Tamboran completed a US$31 million PIPE and raised about US$188 million net in an April 2026 public and entitlement offer. Combined, these equity financings materially increased available cash to fund drilling, stimulation and infrastructure activities through 2026 and 2027.
What is Tamboran Resources’ pro forma cash position after the 3Q FY26 activities?
Tamboran cited pro forma cash of about US$298 million after the April 2026 capital raise. This figure includes a reported US$95 million cash balance at March 31, 2026, plus near‑term cash inflows of about US$203 million from the equity raise and an acreage sale.
How advanced is Tamboran Resources’ Sturt Plateau Compression Facility project?
Tamboran reported the Sturt Plateau Compression Facility was 88% complete at the end of April 2026. The project remains within its P50 budget and schedule, with commissioning targeted in 3Q 2026 to support first gas sales from the Shenandoah South Pilot Project.
What is the size and structure of Tamboran Resources’ farm-out to Daly Waters Energy?
Tamboran agreed to farm down approximately 10,000 acres across the Pilot Area and Beetaloo Central Development Area to Daly Waters Energy. The staged earn‑in provides up to US$28.5 million in carry commitments, supplying non‑dilutive capital to advance development activities.
What were Tamboran Resources’ cash and debt levels as of March 31, 2026?
As of March 31, 2026, Tamboran reported a cash balance of US$95 million, including its share of restricted cash. Net drawn debt associated with constructing the Sturt Plateau Compression Facility was US$23 million, with an additional US$39 million of debt capacity undrawn.