Falcon Oil & Gas Ltd.
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").
-- 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
-- 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
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
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.
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 &
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
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
For further information on Falcon Oil & Gas Ltd. please
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.
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
mMD Metres measured depth
MMscf/d Million standard cubic feet per day
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.
(END) Dow Jones Newswires
September 03, 2021 02:00 ET (06:00 GMT)
Copyright (c) 2021 Dow Jones & Company, Inc.
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