Falcon Oil & Gas Ltd.
(“Falcon”)
Amungee NW-1H – Normalised Gas Flow Rate Equivalent to 5 MMscf/d per 1,000m Horizontal
3 September 2021 – Falcon Oil & Gas Ltd. (TSXV: FO, AIM: FOG) is pleased to provide results of the production log test at the Amungee NW-1H well (“Amungee”). The results suggest a normalised gas flow rate equivalent of between 5.2-5.8 MMscf/d per 1,000m of horizontal section.
Amungee is located in the Beetaloo Sub-basin, Northern Territory, Australia and the testing conducted is part of the 2021 work programme which is operated by Falcon’s joint venture partner, Origin Energy B2 Pty Ltd., a wholly owned subsidiary of Origin Energy Limited (“Origin”).
Amungee Background
- Located in Exploration Permit 98, approximately 60 kilometres east of Daly Waters, just south of the Carpentaria Highway.
- It was the first horizontal well to be drilled and first well to be fracked with Falcon’s JV partner and operator, Origin.
- In November 2015, the JV successfully drilled the well to a total measured depth of 3,808m, including a 1,100m horizontal section.
- In September 2016, 11 hydraulic stimulation stages were completed along the horizontal section in the Middle Velkerri B shale zone.
- In December 2016, a 57-day extended production test (“EPT”) was completed, with production averaging 1.10 MMscf/d.
- In February 2017, the Results of Evaluation of the Discovery and Preliminary Estimate of Petroleum in Place were published for the Velkerri B Shale Gas Pool, confirming a gross contingent resource of 6.6 TCF, 1.46 TCF net to Falcon, full details are contained in Falcon’s AIF.
Details of Amungee Testing
- The well was successfully put back on production testing on 7 August 2021.
- Initial flow rates during the first 48 hours of testing ranged between 2 – 4 MMscf/d with rates averaging 1.23 MMscf/d over the first 23 days.
- A PLT was run on 19 August 2021 to 3,098mMD, just prior to the casing deformation at 3,112mMD.
- The PLT data confirms that:
- Only 5-15% of the production came from stages 1-7 beyond the casing deformation point at 3,112 mMD.
- 85-95 % of the production came from stages 8-11 spanning a 200m horizontal section, prior to the casing deformation.
- The low contribution from stages 1-7 is likely the result of a restriction caused by the casing deformation or the plugs having not milled out, or both.
- Conclusion: stages 8-11 may be representative of the deliverability that can be achieved within the Middle Velkerri B Shale at Amungee.
- The PLT test results equate to a normalised gas flow rate of between 5.2-5.8 MMscf/d per 1,000m of horizontal section.
- A typical future production well would be likely to have a horizontal production section up to three kilometres.
- The result validates the decision to undertake a second EPT in order to run a PLT.
Philip O’Quigley (CEO of Falcon) commented:
“With our unique and extensive position in the Beetaloo Sub-basin, this is really exciting news for Falcon shareholders and this significant development provides line of sight to the commercialisation of the Beetaloo, for which we remain carried for further activity.
A recent report by an industry analyst suggests that gas flows greater than 3MMscf/d from a 1,000m horizontal well are required to demonstrate the commerciality of the Beetaloo. Not only does this test result significantly exceed these parameters and significantly increase our assessment of the Velkerri dry gas play, but it also puts the Beetaloo on a par with other shale gas basins in North America.
While we wait for further news from our operations at Kyalla 117 N2-1H ST2 and Velkerri 76 S2-1, we look forward to working with our JV partner, Origin, in establishing the next phase of work on the Middle Velkerri B Shale.
With other drilling activity in neighbouring Santos-operated blocks targeting the Velkerri dry gas play, this is an important moment for the nationally significant Beetaloo Sub-basin.”
This announcement contains inside information.
Ends.
CONTACT DETAILS:
| Falcon Oil & Gas Ltd. | +353 1 676 8702 |
| Philip O’Quigley, CEO | +353 87 814 7042 |
| Anne Flynn, CFO | +353 1 676 9162 |
| Cenkos Securities plc (NOMAD & Broker) | |
| Neil McDonald / Derrick Lee | +44 131 220 9771 |
This announcement has been reviewed by Dr. Gábor Bada, Falcon Oil & Gas Ltd’s Head of Technical Operations. Dr. Bada obtained his geology degree at the Eötvös L. University in Budapest, Hungary and his PhD at the Vrije Universiteit Amsterdam, the Netherlands. He is a member of AAPG.
About Falcon Oil & Gas Ltd.
Falcon Oil & Gas Ltd is an international oil & gas company engaged in the exploration and development of unconventional oil and gas assets, with the current portfolio focused in Australia, South Africa and Hungary. Falcon Oil & Gas Ltd is incorporated in British Columbia, Canada and headquartered in Dublin, Ireland with a technical team based in Budapest, Hungary.
Falcon Oil & Gas Australia Limited is a c. 98% subsidiary of Falcon Oil & Gas Ltd. Falcon Oil & Gas Australia Limited and a wholly-owned subsidiary of Origin Energy Limited (ASX: ORG) (“Origin”) are joint venture partners in respect of the Beetaloo project.
For further information on Falcon Oil & Gas Ltd. please visit www.falconoilandgas.com
About Origin
Origin is a leading Australian integrated energy company. Origin is a leading energy retailer with approximately 4.2 million customer accounts, has approximately 7,500 MW of owner and contracted power generation capacity and is also a large natural gas supplier. Origin is the upstream operator of Australia Pacific LNG, which supplies natural gas to domestic markets and exports LNG under long term contracts.
www.originenergy.com.au
Glossary of terms
AIF Annual Information Form for the year ended 31 December 2020, dated 26 April 2021.
JV Joint venture between Falcon Oil & Gas Australia Limited and Origin Energy B2 Pty Ltd.
LNG Liquefied natural gas
m Metres
mMD Metres measured depth
MMscf/d Million standard cubic feet per day
MW Megawatt
PLT Production logging tool
TCF Trillion cubic feet
Advisory regarding forward looking statements
Certain information in this press release may constitute forward-looking information. Any statements that are contained in this news release that are not statements of historical fact may be deemed to be forward-looking information. Forward-looking information typically contains statements with words such as “may”, “will”, “should”, “expect”, “intend”, “plan”, “anticipate”, “believe”, “estimate”, “projects”, “dependent”, “potential”, “scheduled”, “forecast”, “outlook”, “budget”, “hope”, “suggest”, “support” or the negative of those terms or similar words suggesting future outcomes. In particular, forward-looking information in this press release includes, but is not limited to, information relating to normalised gas flow rates, the 2021 work programme, the contingent resource estimate for the Amungee NW-1H Velkerri B shale gas pool, comments made with respect to the type, number, schedule, stimulating, testing and objectives of the wells to be drilled in the Beetaloo Sub-basin Australia, the prospectivity of the Middle Velkerri and Kyalla plays and the prospect of the exploration programme being brought to commerciality. This information is based on current expectations that are subject to significant risks and uncertainties that are difficult to predict. The risks, assumptions and other factors that could influence actual results include risks associated with fluctuations in market prices for shale gas; risks related to the exploration, development and production of shale gas reserves; general economic, market and business conditions; substantial capital requirements; uncertainties inherent in estimating quantities of reserves and resources; extent of, and cost of compliance with, government laws and regulations and the effect of changes in such laws and regulations; the need to obtain regulatory approvals before development commences; environmental risks and hazards and the cost of compliance with environmental regulations; aboriginal claims; inherent risks and hazards with operations such as mechanical or pipe failure, cratering and other dangerous conditions; potential cost overruns, drilling wells is speculative, often involving significant costs that may be more than estimated and may not result in any discoveries; variations in foreign exchange rates; competition for capital, equipment, new leases, pipeline capacity and skilled personnel; the failure of the holder of licenses, leases and permits to meet requirements of such; changes in royalty regimes; failure to accurately estimate abandonment and reclamation costs; inaccurate estimates and assumptions by management and their joint venture partners; effectiveness of internal controls; the potential lack of available drilling equipment; failure to obtain or keep key personnel; title deficiencies; geo-political risks; and risk of litigation.
Readers are cautioned that the foregoing list of important factors is not exhaustive and that these factors and risks are difficult to predict. Actual results might differ materially from results suggested in any forward-looking statements. Falcon assumes no obligation to update the forward-looking statements, or to update the reasons why actual results could differ from those reflected in the forward looking-statements unless and until required by securities laws applicable to Falcon. Additional information identifying risks and uncertainties is contained in Falcon’s filings with the Canadian securities regulators, which filings are available at www.sedar.com, including under “Risk Factors” in the Annual Information Form.
Advisory regarding oil and gas information
Any references in this news release to initial production rates are useful in confirming the presence of hydrocarbons; however, such rates are not determinative of the rates at which such wells will continue production and decline thereafter and are not necessarily indicative of long-term performance or ultimate recovery. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production for Falcon. Such rates are based on field estimates and may be based on limited data available at this time.
Contingent resource estimates are those quantities of gas (produced gas minus carbon dioxide and inert gasses) that are potentially recoverable from known accumulations, but which are not yet considered commercially recoverable due to the need for additional delineation drilling, further validation of deliverability and original gas in place, and confirmation of prices and development costs. There is uncertainty that it will be commercially viable to produce any portion of the resources. For additional information relating to contingent resource estimates in respect of the Amungee NW-1H Velkerri B Shale Gas Pool which were prepared by an Origin employee and a Qualified Reserves and Resources Evaluator effective as of February 15, 2017, please refer to Falcon’s Annual Information Form dated April 26, 2021, which is available on SEDAR at www.sedar.com.
Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release.
