Beetaloo Sub-Basin

Background

Falcon Oil & Gas Australia Limited (“Falcon Australia”) is a 98% owned subsidiary of Falcon. Falcon Australia holds 30% interest in 4.6 million gross acres in exploration permits EP76, EP98 and EP117 covering the most prospective core area of the Beetaloo Sub-basin.

The Beetaloo Sub-basin is located in the Northern Territory, 600 kilometres south of Darwin, close to infrastructure including a highway, a pipeline and a railway, offering transport options to the Australian market and beyond via liquefied natural gas (LNG) capacity in Darwin to the north and in Queensland to the east.

The sparsely populated and remote Beetaloo Sub-basin is a relatively underexplored onshore basin of Proterozoic age within the larger McArthur basin. It has excellent unconventional hydrocarbon potential such as shale gas, shale oil and tight gas.

Work was previously undertaken by a Rio Tinto Group subsidiary company, Sweetpea Petroleum, Hess Australia and Falcon Australia. Sweetpea drilled the Shenandoah-1 vertical well, which was deepened by Falcon Australia. Hess acquired 3,490 kilometres of 2D seismic data, to date the largest onshore 2D seismic program in Australia. The seismic database, along with existing well data, provided a solid platform to elaborate and extrapolate a detailed structural and stratigraphic model for the Beetaloo Basin, concluding that the Beetaloo Basin is an active petroleum system.

Transformational Farm Out of Beetaloo unconventional acreage

In August 2014, Falcon Australia completed a A$200 million, nine-well farm-out deal with Origin Energy and Sasol each farming into 35% of Falcon Australia’s exploration permits. In May 2017, Origin acquired Sasol’s interest, bringing its overall interest to 70% in the Beetaloo JV. Origin is operator of the Beetaloo project.

The details of the exploration and appraisal programme were as follows:

• 3 vertical exploration/stratigraphic wells and core studies;
• 1 hydraulic fracture stimulated vertical exploration well and core study;
• 1 hydraulic fracture stimulated horizontal exploration well, commercial study and 3C resource assessment; and
• 4 hydraulic fracture stimulated horizontal exploration/appraisal wells, micro-seismic and 90 day production tests.
• Farminees to pay the full cost of the following two horizontally fracture stimulated wells, 90 day production tests and micro seismic data collection with a capped expenditure of A$53 million, any cost overrun funded by each party in proportion to their working interest.
• Farminees to pay the full cost of the final two horizontally fracture stimulated wells and 90 day production tests capped at A$48 million, any cost overrun funded by each party in proportion to their working interest.

In August 2018 Falcon signed an agreement to amend the Farm Out Agreement with Origin, to deem Stage 1 of the exploration and appraisal drilling programme in the Beetaloo Sub-basin complete and to commence Stage 2 with a A$15 million increase to the Stage 2 Cost Cap.

Work Programme

The Beetaloo JV has a 3 stage work program to explore and appraise the asset with the following main objectives:

Stage 1  Prove the presence, quality and continuity of the Velkerri shale play
Stage 2  Evaluate the potential of liquids fairways in the Velkerri and Kyalla shale plays
Stage 3  “Test the Best” – confirm commercial production rates and EURs in most prospective play

Stage 1 – Exploration & Discovery

Stage 1 was completed with the successful drilling of 3 vertical wells and the drilling and the subsequent multi-stage hydraulic fracturing and extended production testing of a horizontal well. The technical work in Stage 1:

• proved the Middle Velkerri shales as pervasive, stacked play fairways in various maturity windows (dry to wet gas) continuous over >80 km;
• identified three organic rich shale intervals (A, B & C shales) in the Middle Velkerri sequence;
• found the gross thickness of Middle Velkerri ~500 m, net pay in B and C shales >50 m each;
• found an average total organic carbon (“TOC”) 3-4 % in prospective shale intervals along with excellent gas shows;
• demonstrated excellent reservoir and completion quality;
• confirmed favourable geomechanics and good frackability of target shales;
• estimated gas in-place density comparable to successful North American shale plays.

The Amungee NW-1H horizontal well was completed with 11 hydraulic stimulation stages in the 1,000 m long horizontal section within the Middle Velkerri B shale zone. The production well test took 57 days. Early stage gas flow rates through 4 1/2” production casing regularly reached over 1-1.5 MMscf/d. Extended flow test rates through 2 3/8″ production tubing ranged between 0.8-1.2 MMscf/d. Test results in the Amungee NW-1H well proved up the discovery of gas accumulation in the Middle Velkerri B shale.

Notification of Discovery and Declaration of a Material Gas Resource

Following the completion of the extended production testing at the Amungee NW-1H exploration well of the “B Shale” member of the Middle Velkerri Formation, Origin submitted a notification of discovery and an initial report on discovery (“Notification of Discovery”) to the Department of Primary Industry and Resources of the Northern Territory, Australia (“DPIR”) in October 2016.

Subsequently, in February 2017 it was announced that Origin had submitted the Results of Evaluation of the Discovery and Preliminary Estimate of Petroleum in Place for the Amungee NW-1H Velkerri B Shale Gas Pool (“Report”) to the Northern Territory Government and had also prepared a contingent gas resource estimate.

Middle Velkerri B Shale Volumetric Estimates (¹)

¹ The Report and estimates included in the table above were not prepared in accordance with COGEH

Assessment of 2C Contingent Gas Resource Estimates for the Middle Velkerri B Shale Pool within EP76, EP98 and EP117 as of 15 February, 2017¹

¹ Contingent resource estimates have been prepared on a statistical aggregation basis and in accordance with the Society of Petroleum Engineers Petroleum Management System (SPE-PRMS).  If the estimates were to be prepared in accordance with COGEH, Falcon is highly confident that there would be no change to the contingent resource estimates above.

Full details relating to the above technical recoverable resource and gross contingent resource can be found here.

Additional Plays

In addition to the Velkerri shale dry gas play, considered presently as the most materially and technically mature resource, Origin has identified four additional play types in the Beetaloo Basin:

Kyalla shale and hybrid liquids rich gas plays

• Two source rock and two hybrid target intervals in Kyalla Fm.
• Estimated CGR at 15-60 bbl/MMscf
• Kyalla Fm. prospective areas confined to central part of JV permits
• Likely cost advantage over the Velkerri given it is shallower (1,500m v’s 2,500m)
• Likely to be wet gas that could also improve economics considerably
• Could lead to a ‘stacked’ play development along with Middle Velkerri shales

Velkerri shale liquids rich gas play

• Liquids rich gas play fairway along the northern and south-eastern flanks at 1,200-2,000 mTVD
• Good reservoir and completion quality in wet gas window, estimated CGR at 5-40 bbl/MMscf
• Indications that porosity and permeability are higher in these areas.

Hayfield sandstone oil/condensate play

• Regionally extensive sandstone in the northern part of permits
• Tight sand, stratigraphic trapping
• Penetrated, DST’d in Amungee NW-1 well

Stage 2 – Explore & Appraise Additional Play Types

The Stage 2 exploration and appraisal drilling program will evaluate the potential of the liquids rich gas fairways in both the Kyalla and Velkerri shales to determine the most commercially prospective play to be targeted during Stage 3. Field activities planned for 2019 will include the drilling of one vertical well and the drilling and hydraulic fracture stimulation of two horizontal wells.

An early commitment to Stage 3 capital expenditure during 2019 was also agreed, enabling an efficient transition from Stage 2 to Stage 3, in the case that Origin and Falcon agree to proceed to Stage 3.

Stage 3 – Test the Best

Stage 3 will focus on the most prospective play type identified in Stage 1 and 2 by drilling and hydraulic fracture stimulation of two horizontal wells.

2019 Updates

21 January 2019 – Rig Contract Signed

On 21 January 2019 Falcon announced that Origin had signed a rig contract with Ensign Australia Pty Ltd. for Rig 963 for the 2019 Stage 2 Beetaloo drilling programme, with an option to extend the contract into 2020.

Subject to relevant approvals, and implementation of the exploration recommendations of the Inquiry into Hydraulic Fracture Stimulation in the Northern Territory, the JV will evaluate the potential of the liquids-rich gas fairways in both the Kyalla and Velkerri plays. Exploration and appraisal activities include the drilling and hydraulic fracture stimulation of two horizontal wells. Together with the Velkerri B dry gas play discovered in 2016, this allows for the assessment of three plays, enabling the most commercially prospective play to be targeted for Stage 3 drilling during 2020.

As of 21 January 2019 work had already commenced at some well sites, including water bore drilling and water monitoring, with drilling targeted to commence in June 2019.

3 May 2019 –  Kyalla 117 N2 Exploration Well EMP Accepted for Assessment

On 3 May 2019, Falcon announced that the Environmental Management Plan (“EMP”) for the Kyalla 117 N2 Exploration well, for the planned 2019 drilling, stimulation, and well testing prepared by Origin on behalf of the JV, has been accepted for assessment by the Northern Territory Department of Environment and Natural Resources (“DENR”).

The EMP provides detail on how Origin will ensure the environmental impacts and risks associated with its activities are reduced to a level that is as low as reasonably practicable and acceptable. The EMP has been prepared with reference to regulatory obligations and relevant Inquiry recommendations that have underpinned the Code of Practice for Petroleum Activities in the Northern Territory.

22 August 2019 – Kyalla 117 N2 Horizontal Appraisal Well EMP Approved

On 22 August 2019, Falcon announced that the EMP for the Kyalla 117 N2 horizontal appraisal well, had been approved by DENR.

Kyalla 117 N2 Horizontal Appraisal Well

• The well is targeting the Kyalla shale liquids rich gas fairway
• Construction of the well pad and related civil works is nearing completion
• Drilling operations will commence in September

9 October 2019 – Spudding of the Kyalla 117 N2-1 Appraisal Well

On 9 October 2019, Falcon announced the spudding of the Kyalla 117 N2-1 appraisal well in the Beetaloo Sub-Basin.

Highlights:

• Kyalla 117 N2-1 is the first well in the Stage 2 drilling programme to target the Kyalla shale liquids rich gas play.
• Located within Exploration Permit 117 approx. 32 kilometres north of the Beetaloo W-1 well.
• A vertical pilot hole will target a total vertical depth of approximately 1,750 metres into the Kyalla Formation.
• A subsequent horizontal section is planned for approximately 1,000 metres that will be drilled, completed, stimulated and production tested in the prospective Kyalla shale reservoir interval.
• Origin Energy B2 Pty Ltd (“Origin”), as Operator, will drill the Kyalla 117 N2-1 well.
• Origin hold a participating interest of 70% and Falcon Oil & Gas Australia Limited hold the other 30% participating interest over the Beetaloo Exploration Permits, 76, 98 and 117.

The principal objectives for the drilling of the Kyalla 117 N2-1 well are to:

• Penetrate the Kyalla Formation to assess hydrocarbon maturity, saturation and reservoir quality.
• Provide further information on the areal distribution of the Kyalla Formation.
• Collect data for subsequent horizontal drilling, completion, stimulation and production testing; including ability to flow liquids rich gas.

Formation evaluation, including reservoir characterisation, will be carried out through petrophysical interpretation, geo-mechanical studies and core analysis.