SS-2H ST1 Delivers Record Beetaloo Basin IP90 Flow Rate, Maintaining Stable Gas Rate Over the Final 30-day Period
Highlights
- The Shenandoah South 2H sidetrack (SS-2H ST1) well achieved a Beetaloo Basin record average 90-day initial production (IP90) flow rate of 6.7 million cubic feet per day (MMcf/d) over a 5,483-foot stimulated horizontal within the Mid Velkerri B Shale.
-
Over the last 30 days, flow rates from the SS-2H ST1 well have increased by ~
2% without any downhole intervention and maintaining a 44/64” choke. -
At the completion of the 90-day period, the well was flowing at 6.5 MMcf/d with a wellhead pressure of ~700 psi, a ~
3% decline from the end of Day 60. - The SS-2H ST1 well has now been suspended ahead of the commencement of gas sales to the Northern Territory Government via the Sturt Plateau Compression Facility (SPCF) in mid-2026, subject to weather conditions and final stakeholder approvals.
- The three well 2025 Shenandoah South drilling campaign continued to progress with the intermediate section of the SS-5H and -6H wells successfully drilled. The rig is currently drilling the intermediate section of the SS-4H well. The campaign is the first multi-well drilling program implementing batch drilling in the Beetaloo Basin.
- On completion of the intermediate section of the SS-4H well, the rig is planned to commence drilling of the 10,000-foot horizontal sections of the three wells.
Figure 1: SS-2H ST1 IP90 flow rate vs. SS-1H and T3H. Source: Company data
Tamboran Resources Corporation Chairman and Interim CEO, Richard Stoneburner, said:
“The performance and character of the SS-2H ST1 well is unique compared to hundreds of wells I have seen in my career. With flow rates increasing over the last 30 days to 6.5 MMcf/d, without downhole intervention or adjustments to choke, I believe we are seeing the enhanced matrix connectivity achieved during the stimulation program. The SS-2H ST1 well represents another encouraging data point as we better understand the Velkerri B Shale’s ultimate performance and recovery.
“Most importantly, at the end of the 90-day period, the well continued to slowly clean up, suggesting that it could have sustained the current rate beyond the testing interval. This data will be important as we prepare to stimulate our first 10,000-foot horizontal section in the Shenandoah South area by the end of the year.
“These results, combined with the SS-1H flow rates in 2024, show the significant potential of the large acreage position surrounding the Shenandoah South area, where we are currently progressing a farm down of ~400,000 acres. The farm down acreage is expected to be developed over the coming years to supply into the anticipated shortfall emerging in the East Coast gas market.”
Shenandoah South 2H ST1 flow results
The SS-2H ST1 well in Tamboran-operated Exploration Permit (EP) 98 achieved an average IP90 flow rate of 6.7 MMcf/d with cumulative production of 601.2 MMcf following the 35-stage stimulation program across a 5,483 feet (1,671 metres) lateral section in the Mid Velkerri B Shale.
Over the 90-day period, the flowing wellhead pressure was drawn down from 4,565 to ~700 psi. During the 30-day testing period from Day 61 to 90, gas rates increased from 6.4 MMcf/d to 6.5 MMcf/d. Over the final 30 days, the well achieved an average flow rate of 6.4 MMcf/d with cumulative production of 192.8 MMcf. The flowing wellhead pressure was drawn down from 722 to 700 psi. The choke size was unchanged at 44/64”.
Table 1: Breakdown of the SS-2H ST1 IP90 flow result
|
Average gas rate
|
IP90 decline rate (%) |
IP1 (Choke 16/64” – 20/64”) |
8.2 |
( |
IP5 (Choke 16/64” – 34/64”) |
8.8 |
( |
IP10 (Choke 34/64” – 40/64”) |
7.2 |
( |
IP30 (Choke 40/64”) |
6.6 |
( |
IP45 (Choke 40/64” – 44/64”) |
6.4 |
|
IP60 (Choke 44/64”) |
6.4 |
|
IP90 (Choke 44/64”) |
6.5 |
- |
Source: Company data |
||
Figure 1: SS-2H ST1 IP90 flow rate vs. SS-1H and T3H
Source: Company data
Figure 2: Flow tests from Beetaloo Basin wells at Shenandoah South compared to wells drilled in the Marcellus Shale in the dry gas area. SS-2H ST1 aligns with average IP90 rates from more than 11,000 well data set
Note: SS-1H initial 90-day and SS-2H initial 90-day production plotted against average of wells within the Marcellus shale, grouped by operator, normalized to 10,000 ft lateral length. First month production for Marcellus based on first full calendar month of production; SS-1H and SS-2H ST1 wells commenced testing following a “soaking” period of three weeks and ~60 days respectively. SS-1H average 90-day gas rate of 2.9 MMcf/d for 500-metres (~1,640 ft) stimulated lateral length normalized to 10,000 ft, shown in red. SS-2H ST1 average 90-day gas rate of 6.7 MMcf/d for 1,671-metres (~5,483 ft) stimulated lateral length normalized to 10,000 ft, shown. Marcellus comparison includes 11,452 wells with minimum 12 months of production from the following operators: Antero Resources, Expand, CNX Resources, Coterra Energy, EQT, HG Energy, Olympus Energy, Range Resources, and Repsol. Marcellus Production Data Source: Enverus Prism Foundations™ Forecast Analytics (Data accessed June 12, 2025).
Figure 3: Relative performance between SS-1H and SS-2H ST1 from Day 31
Source: Company data
This announcement was approved and authorised for release by Dick Stoneburner, the Chairman and Interim Chief Executive Officer of Tamboran Resources Corporation.
About Tamboran Resources Corporation
Tamboran Resources Corporation (“Tamboran” or the “Company”), through its subsidiaries, is the largest acreage holder and operator with approximately 1.9 million net prospective acres in the Beetaloo Sub-basin within the Greater McArthur Basin in the
Tamboran’s key assets include a
The Company has also secured ~420 acres (170 hectares) of land at the Middle Arm Sustainable Development Precinct in Darwin, the location of Tamboran’s proposed NTLNG project. Pre-FEED activities are being undertaken by Bechtel Corporation.
Table 2: Disclosures under ASX Listing Rule 5.30 (Shenandoah South 2H ST1)
a) The name and type of well.
Shenandoah South 2H horizontal sidetrack (SS-2H ST1) well.
b) The location of the well and details of the permit or lease in which the well is located.
EP 98 of Beetaloo Sub-basin,
c) The entities working interest in the well.
Tamboran holds a
d) If the gross pay thickness is reported for an interval of conventional resources, the net pay thickness.
Not applicable—this is not a conventional reservoir.
e) The geological rock type of the formation drilled.
Organic-rich shale.
f) The depth of the zones tested.
Average depth of horizontal 3,017 metres Total Vertical Depth (TVD) (9,899 feet TVD), with 1,671 metres (5,483 ft) of stimulated lateral length.
g) The types of test(s) undertaken and the duration of the test(s).
90-day initial production (IP90) gas flow test.
h) The hydrocarbon phases recovered in the test(s).
Dry gas - mole %. Methane – 91.7, Ethane – 2.7, Propane – 0.12, Butane & higher <0.05.
i) Any other recovery, such as, formation water and water, associated with the test(s) and their respective proportions.
Fracture stimulation fluid is being recovered during testing. The well is currently producing between 40 and 70 barrels of water per day with a cumulative 26,695 bbls of water recovered from day 1 of cleanup.
j) The choke size used, the flow rates and, if measured, the volumes of hydrocarbon phases measured.
The SS-2H ST1 well in Tamboran-operated Exploration Permit (EP) 98 achieved an average IP90 flow rate of 6.7 MMcf/d with cumulative production of 601.2 MMcf following the 35-stage stimulation program across a 5,483 feet (1,671 metres) lateral section in the Mid Velkerri B Shale. Over the 90-day period, the flowing wellhead pressure was drawn down from 4,565 to 700 psi, with the choke adjustments from 10/64” to 40/64” over the first 30 days and further adjustments from 40/64” to 44/64” during period of Day 38 to 39.
During the 30-day testing period from Day 61 to 90, gas rates increased from 6.4 MMcf/d to 6.5 MMcf/d. The well achieved an average 30-day flow rate of 6.4 MMcf/d with cumulative production of 193.1 MMcf. The flowing wellhead pressure was drawn down from 722 to 700 psi. The choke size was unchanged at 44/64”.
k) If applicable, the number of fracture stimulation stages and the size and nature of fracture stimulation applied.
35 stage fracture stimulation stages and a toe stage covering over 1,671 metres (5,483 feet) at an average of 40 to 50-metre (131 - 164-foot) interval spacing within the Mid Velkerri B Shale. Average proppant concentrations of 2,706 lbs/ft across the 35 main stages with a total of over 14 million pounds of sand placed.
l) Any material volumes of non-hydrocarbon gases, such as carbon dioxide, nitrogen, hydrogen sulphide or sulphur.
Reported as Mol %: CO2, – 3.5, N2 – 1.9, He – 0.1.
m) Any other information that is material to understanding the reported results.
Following the completion of the 90-day flow test, the well was suspended ahead of the commencement of gas sales to the Northern Territory Government via the SPCF in mid-2026, subject to weather conditions and customary stakeholder approvals.
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
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.
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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
Source: Tamboran Resources Corporation
