ANNUAL REPORT 2019 ANNUAL GENERAL MEETING
The 2019 Annual General Meeting will be held at Amora Hotel
Jamison Sydney, 11 Jamison Street, Sydney NSW 2000,
on 28 November 2019, commencing at 11.00 a.m.
The Notice of Meeting and Proxy Form have been mailed
separately from this Annual Report.
Front Cover Images:
Ensign 950 drilling Jarrar 5 oil appraisal well
Naccowlah Block SW Queensland.
October 2018
K E Y O U T C O M E S & O U T L O O K
OIL PRODUCTION AND
DEVELOPMENT
Bounty group achieved record oil revenue in Queensland of $3.66 million in 2019 with:-
• Tie-in of successful Birkhead zone oil appraisal wells at Watkins and other Fields;
Naccowlah Block, South-West Queensland
• Drilling 11 appraisal and NFE wells with 8 successful completions
• Planning for a further 9 appraisal wells in 2020
• Improving oil output and strong A$ oil prices at around A$90
Naccowlah drilling expected to further increase 2019 oil reserves
OIL AND GAS EXPLORATION
AND DEVELOPMENT
• Bounty oil and gas exploration and development acreage in Surat Basin will
underwrite future resource and revenue growth
• Operator progressing to drill PEP 11 Sydney Basin in 2021
FULL YE AR 2019 - RESULTS
• Group petroleum revenue for the year up 130% to $3.66 million (2018: $1.57
million) primarily due to increased Queensland oil sales
• Operating profit of $1.12 million (2018: loss $0.27 million) before non-cash
expenses
• Cash and current assets at 30 June 2019 were $1.47 million with nil debt
Bounty Oil & Gas NL Annual Report - 2019
TABLE OF CONTENTS
Key Outcomes
Chairman’s Review
CEO’s Review
Project and Operations Review
Corporate Governance Statement
Page
Inside
Cover
2
3 – 5
6 – 15
16
Directors Report including Remuneration Report
16 – 27
Auditor's Independence Declaration
Consolidated Statement of Comprehensive Income
Consolidated Statement of Financial Position
Consolidated Statement of Changes in Equity
Consolidated Statement of Cash Flows
Contents of the Notes to and Forming Part of the
Financial Statements
Directors Declaration
Independent Auditors Report to Members
28
29
30
31
32
33 – 55
56
57 – 59
Website
Bounty maintains a website at:
www.bountyoil.com
On our website you will find full
information about the Company.
Every announcement made to
the Australian Securities
Exchange (ASX) is published on
the website. You will also find
detailed information about the
Company's Exploration and
Production Permits.
Stock Exchange Listing
Bounty Oil & Gas N.L. securities
are listed on the Australian
Securities Exchange.
Additional Information Required by ASX Listing Rules
60 – 61
ASX Code: BUY
Schedule of Petroleum Tenements
Abbreviations
Corporate Directory
62 – 63
64 – 65
66
Bounty Oil & Gas NL
ACN: 090 625 353
ABN: 82 090 625 353
Annual General Meeting:
The 2019 Annual General Meeting will be held at Amora Hotel Jamison Sydney, 11 Jamison Street, Sydney NSW 2000,
on 28 November 2019, commencing at 11.00 a.m.
The Notice of Meeting and Proxy Form have been mailed separately from this Annual Report.
Bounty Oil & Gas NL Annual Report – 2019
CHAIRMAN’S REVIEW
Dear Shareholder
Bounty has had a very successful year on both the drilling and oil production fronts. Your company has achieved
record petroleum revenue for the year of $3.66 million from oil produced from Naccowlah Block, SW Queensland.
Our oil is exported from the Naccowlah Block through a series of transport pipelines west to Moomba and then
south to Port Bonython in South Australia. It is at this delivery point that the Naccowlah Block Joint Venture oil is
sold and priced. So, as a result of this efficient delivery system Bounty is now regularly receiving increased oil
revenue in a very low sovereign risk project and investing back into oil reserve accretion.
Based on this revenue increase Bounty achieved an operating profit of $1.11 million before non-cash expenses. This
was an increase of 130% on the previous year. Although your Board is pursuing unpaid gas revenue from the
Tanzania Joint Venture your Board decided to fully impair the net receivables and the Tanzanian investment. As a
result the net loss after non-cash items was $2.78 million.
On the positive asset side Bounty was more than compensated for by our participation in a continuing highly
successful appraisal drilling campaign into the Birkhead and Westbourne zones in the Na ccowlah Block.
11 wells were drilled during the period out of which 8 were cased for production and completion. In addition we
continued to invest in significant production infrastructure upgrades including new pipelines in Watkins Field and
other fields within the Block.
The successful drilling result in Naccowlah Block has allowed Santos Limited as operator to propose up to an
additional 9 appraisal wells in the Block in the coming financial year. This exciting additional drilling will again
increase our very conservatively stated Naccowlah Block oil reserves and provide steady oil revenues in coming
years.
Bounty is building its cash and current assets apart from building oil reserves and investing in new infrastructure. As
we strengthen our balance sheet Bounty will commence development of our very significant Surat Basin, SE
Queensland oil and gas reserves.
Bounty is also continuing to participate in PEP 11 Offshore Sydney Basin and the operator is planning to drill a major
gas target in PEP 11 in 2020.
Bounty is confident about its future in a world which continues to demand high quality oil and where there is a gas
shortage in East Australia.
I again thank shareholders for their patience and support while we move through this exciting growth phase. I
would particularly like to thank my other Board members and our dedicated staff and consultants for their great
work in this successful year.
Graham Reveleigh
Chairman
29 October 2019
2
Bounty Oil & Gas NL Annual Report – 2019
CEO’S REVIEW
Highlights for the Year:
•
•
•
•
•
•
Bounty achieved record petroleum revenue up 130% to $3.66 million (2018: $1.57 million) mainly from oil
sales in Australia.
Operating profit of $1.11 million (2018: operating loss $0.27 million) before non-cash expenses including
impairment and amortisation of oil & gas assets of $3.9 million.
Net loss after these non-cash items of $2.78 million (2018: $2.08 million loss).
Cash and current assets at 30 June 2019 were $1.47 million (2018: $2.48 million) with nil debt.
Bounty participated in another successful drilling program in 2019 adding to reserves and oil revenue.
Bounty is planning to maintain and potentially increase oil production in 2020 from its Cooper Basin assets by
participating in 9 additional appraisal and NFE oil wells in the Naccowlah Block while pursuing
commencement of oil production in the Surat Basin, Eastern Queensland.
Introduction
Bounty’s petroleum revenue was at an all-time record and we anticipate that it will exceed $3 million in 2020 by
further contributions from the recent Birkhead zone discoveries in Naccowlah Block and 9 additional wells. Bounty
added to its production tangibles by participating at its share of new pipeline and oil production infrastructure builds
in Naccowlah Block.
See the Directors Report for further 2019 production and revenue details.
Bounty has withdrawn from the Tanzania gas project and fully expensed its investment but will pursue long delayed
gas sales revenue.
2020 Forward Plans
Bounty will participate in 9 additional appraisal wells in Naccowlah Block with an anticipated 4 wells at Jarrar Field
and 5 at Cooroo Field. These wells will again increase production and oil reserves.
Bounty is completing planning to recommence oil production from PL 2 Alton and gas production from PL 441
Downlands; near Surat, Queensland. Bounty finally obtained renewal of PL 441 Downlands in June 2019.
Bounty has other Surat Basin gas exploration opportunities to contribute to future revenue growth in the
reconstituted ATP 2028P.
Bounty holds 15% of PEP 11 Offshore Sydney Basin in what has the potential to lead up to a new exploration drill of a
major gas exploration project near Newcastle, NSW. Offshore operations are not affected by the various onshore gas
exploration road blocks and planning is underway aimed at advancing the Baleen Prospect to a drill test in 2020.
At Rough Range, Western Australia Bounty has 100% ownership of the Rough Range Oilfield and will continue seismic
studies.
More details on current projects are set out in the Project and Operations Review.
Onshore Projects
Oil Business
SW Queensland – Cooper Basin
Oil production from the Santos Limited operated ATP 1189 Naccowlah Block tripled with an increase to 39,792 bbls
(2018: 13,162 bbls). With rising oil prices in $A terms revenues jumped 130% to $3.66 million.
3
Bounty Oil & Gas NL Annual Report – 2019
In May 2018 Bounty participated in two exceptional oil appraisal wells at the Watkins Field in the Naccowlah Block.
These wells were tied in with new pipelines and production infrastructure. Subsequently, during the period Bounty
participated in a further series of 11 appraisal and NFE oilwells, with 8 cased for production and 4 P & A’d. This
exceptionally successful program has increased Bounty’s oil reserves in Naccowlah Block and lifted oil revenue for the
year to a record. Details of the wells are set out below in the Project and Operations Review below.
Significant sales volumes will continue to come from additional Birkhead and Westbourne zone discoveries at
Watkins Field, Jarrar Field and other Fields within Naccowlah Block. The joint venture is planning a further 9
Naccowlah appraisal wells in the current financial year.
Revenue of $3.0 million is anticipated for 2019/2020 with upside potential from participation in 9 additional appraisal
wells.
SE Queensland – Surat Basin
Petroleum Lease 2 Alton (PL2) – see Maps in Project and Operations Review below.
Bounty is now operator of Petroleum Lease 2 and holds:
100% of the Alton Oilfield and Alton Block.
•
• Alton is 440 km west of Brisbane and Alton oil will be transported and sold into the Brisbane Refinery.
• Development reserves: 167,000 bbls of recoverable oil in the early Triassic age Basal Evergreen sand
reservoir plus potential 1.136 million bbls of 2P reserves located in the three sands of the Boxvale/Evergreen
Formations.
Production facilities at Alton Oilfield.
Surrounding exploration acreage where there is considerable potential for further resource additions with
undrilled locations and attic oil in the Evergreen Formation and possibly extensive oil in the lower
Showgrounds Formation which has been proven as a high productivity sand in the area.
•
•
• Bounty holds an 81.75% interest in the Kooroon JV within PL2 Alton and thereby controls appraisal of the
Eluanbrook Updip target in PL 2.
Bounty is now planning to commence oil production at PL 2 Alton in 2020 which is expected to generate additional
revenue of up to $1 million per annum with significant upside from four undrilled locations; enhanced recovery and
later an appraisal well at Eluanbrook (see below).
Petroleum Lease 441 Downlands (PL 441) – see Maps in Project and Operations Review below.
During the period Bounty obtained renewal of PL 441 Downlands and commenced facility reviews and compliance
activities. The PL 441 production infrastructure and pipeline is connected to the Silver Springs – Wallumbilla trunk
line and Bounty is studying gas production feasibility.
Western Australia – Carnarvon Basin
Petroleum Lease L 16, Rough Range
During the period the group relinquished EP 435 and EP 357. It conducted well integrity tests on the Rough Range 1B
well in Petroleum Licence L 16 onshore Carnarvon Basin and other remediation at the Rough Range Oilfield.
Bounty is planning a full seismic and geological review at L 16 in 2020.
Unconventional Gas Business
Looming gas supply shortages in eastern Australia continue to provide encouragement for the pursuit of conventional
and unconventional gas in PRL’s (formerly PEL 218) (Nappamerri Project); Cooper Basin, South Australia where Bounty
holds a 24.8% interest and for deep gas in some of Bounty’s other permits principally the Farawell Updip Showgrounds
Formation prospect in ATP 2028P (formerly ATP 754P); Surat Basin.
4
Bounty Oil & Gas NL Annual Report – 2019
Offshore Projects - Growth
PEP 11; New South Wales
The operator Asset Energy Pty Limited undertook a 2D seismic survey in March 2018 and the permit is in good
standing. Control of the operator reverted to interests associated with Mr David Breeze and Bounty and Asset have
co-operated to advance to a drill test of the previously well-defined Baleen Prospect in 2020. With major gas supply
issues developing in eastern Australia; the operator has identified a new target at Baleen Prospect with AVO analysis
of seismic data.
AC/P32 Ashmore Cartier - Timor Sea
AC/P32 is located in the Ashmore Cartier region in the oil prone and prolific Vulcan Graben region.
Bounty’s efforts at farming out AC/P 32 were made difficult by heavy oil price declines in 2016 and 2017 and Bounty
is reviewing the future of this project. The Wisteria prospect is located 25 km northeast of the Montara Oil
Development in the Timor Sea.
Tanzania – Kiliwani North & Nyuni Area PSA
Bounty fully impaired the Kiliwani North assets in the period at a non-cash cost of $1.056 million. Although impaired
Bounty is pursuing its share of gas sales revenue from prior periods.
Further; Bounty withdrew from the Nyuni PSA and has fully impaired its investment with a net non-cash expense of
$1,696,751.
Conclusion
Oil revenue is expected to be $3.0 million in 2020.
Australia confronts the challenge of finding more domestic oil and gas. Bounty increased its oil reserves in the year
to 31 December 2018 and is well placed for additional oil reserve growth at end 2019 and into 2020. It will look for
growth preferably through focus on Bounty operated projects.
Management will pursue additional oil opportunities from within its own operated oil resources at Alton in the Surat
Basin which will be placed on production in 2020. Further afield it will fully review the seismic and other data in the
Rough Range permit and seek partners for an exploration well in PL 16 Rough Range.
On the growth front Bounty is seeking additional opportunities so shareholders may also obtain good leverage.
Bounty holds excellent Permits as has been demonstrated by the Naccowlah Block successes.
PHILIP F. KELSO
Chief Executive Officer
29 October 2019
5
Bounty Oil & Gas NL Annual Report – 2019
PROJECT and OPERATIONS REVIEW
Bounty Projects
Bounty has production and exploration operations in five states and territories within Australia.
Summary Land Position
Offshore Australia
AC/P32
PEP-11
Onshore Australia
Naccowlah SW Queensland
Nappamerri South Australia
Surat Basin Queensland
Rough Range Carnarvon Basin WA
Totals
Equity
100%
15%
2%
23.28%
Various
10%
Gross Km2 Net Km2
336.0
4576.4
1952.3
859.0
808.0
79.5
336.0
686.5
39.0
200.0
461.6
8.0
8611.2
1731.0
This table summarises Bounty’s land position as at 30 June 2019. Bounty’s full schedule of tenements as at 27
September 2019 is included in Additional Information Required by ASX Listing Rules at the end of this Annual Report.
During the year Bounty withdrew from all its Tanzania assets.
Bounty projects not specifically referred to below in this Project Review are summarised in Bounty’s 2018/19
Quarterly Activity Reports to the ASX and on Bounty’s website: www.bountyoil.com
6
Bounty Oil & Gas NL Annual Report – 2019
OIL BUSINESS
SW Queensland – Cooper Basin
Production
Bounty’s petroleum production and sales for the year ended 30 June 2019 are summarised in the Review of
Operations set out in the Directors Report. On a quarter to quarter comparison Bounty’s production trebled from year
end 2018 to year end 2019.
Development
ATP 1189P Naccowlah Block and Associated PL’s SW Queensland - Bounty 2%
Location: Surrounding Jackson, Naccowlah and Watson Oilfields
Background
The Naccowlah Block covers 1794 km2, 9% of which is covered by ATP 1189P and the remainder in 25 petroleum leases
(PL’s) and applications covering producing fields. There is significant production infrastructure and pipelines. Bounty’s
share of production from the Naccowlah Block was 39,792 bbls of oil equivalent for the year. Bounty holds 2P + 2C
(Contingent) reserves of 169,000 bbls a 33% increase over 2018/19. The increase in both production and reserves
was due to a very successful drilling programme of 11 wells during the period.
7
Bounty Oil & Gas NL Annual Report – 2019
2018 / 2019 Naccowlah Block Drilling
The operator Santos Limited undertook further near field exploration (NFE) and development drilling in the 12
months ending 30 June 2019 and Bounty participated in all wells with the following results:-
Well
Wallis 1
Wenda 1 NFE
Cooroo NW 2
Results
Cased for production
P & A
Cased for production
Pallano East 1
P & A
Jarrar 5
Jarrar 4
Cased for production
Cased for production
Watson North 2
Cased for production
Watson North 3
Cased for production
Watkins 4
Watkins 5
Watkins 6
Cased for production
Cased for production
P & A
As a result of drilling in 2018 the Naccowlah Block 2P reserves increased 25% in the 2018 calendar year. Bounty
anticipates that the above 2019 drills will lift 2P reserves at end 2019. After the period Bounty also participated in a
further oil discovery with the Tennaperra 9 well.
2019 / 2020 Naccowlah Block Development
Following on from the drilling success in 2018/19 another 9 appraisal wells are planned for 2019/20 which with
continuing production optimisation will provide stable production.
Production infrastructure builds will continue.
8
Bounty Oil & Gas NL Annual Report – 2019
SE Queensland - Surat Basin
Oil and Gas Development
Surat Basin (South)
Alton Area
Alton Oilfield
Kooroon JV Block
Surat Basin (North)
Downlands Gas Field
Spring Grove JV
Group Interests in the Surat Basin are
Permit
Status
Interest
PL 2 C - Alton Oilfield
PL 2 A & PL 2 B
ATP 2028
PL 441
PCA 159 (ATP 1190 SG)
Renewing
Renewing
Granted
Granted
Renewing
100.0%
81.75%
50.0%
100.0%
24.75%
9
Bounty Oil & Gas NL Annual Report – 2019
Location: From Surat to Alton Oil Field, SE Queensland
Background
Bounty initially gained an interest in the Surat Basin through the purchase of Ausam Resources Pty Ltd in 2009 and
has added to the acreage through strategic acquisition. In 2016 it acquired full control of PL 2. Hydrocarbons in the
southern part of the Surat Basin are generated in the underlying Bowen Basin Permian sequence and are liquids rich.
The oil is trapped in the Triassic age Showgrounds Sandstone and in the Evergreen Formation.
The northern section of Bounty's acreage includes the Permian age Tinowan Formation which frequently has a liquids
rich gas charge and in places, like Bounty's PL 441 Downlands property, good porosity and permeability. PL 441 was
renewed during the period and preparations are underway to re-open the gas plant and pipeline and bring the field
back into gas production, provided the economics “stack up”. The shortage of domestic gas in the Eastern states
means there is a ready market for the gas.
Surat Basin (South)
Oil Development
PL 2 C Alton - Bounty 100% and PL 2 B and 2 C Kooroon Block – Bounty 81.75%
Location: 70 km East of St George SE Queensland
10
Bounty Oil & Gas NL Annual Report – 2019
Background
PL 2 C (Alton Field) has to date produced over 2 million barrels from the Jurassic Age Evergreen Formation. Bounty
estimates 2P reserves at Alton of 0.216 million bbls.
2019 Operations
Bounty completed important amendments to its PL 2 environmental permits; database refinement and geological
studies. Bounty is still working through certain regulatory requirements and environmental studies. An independent
environmental audit and dam assessment gave the field a “clean bill of health”.
2019/20 Plans
Bounty plans to work over 2-3 wells at Alton and commence oil production while it generates a full field development
plan including drilling an up-dip appraisal well at Eluanbrook in the northwest section of PL 2 B and up to 3 attic oil
locations within Block 2 C - the Alton Pool. Initial production of 100 bopd is expected from the Evergreen Formation
and then moving to develop attic oil with potential recoverable oil of 167,000 bbls. Bounty is targeting 350,000 bbls
of oil within known pools in PL 2.
Oil and Gas Exploration
ATP 2028 – Bounty 50%
Location: 70 km East of St George SE Queensland
Background
Bounty has renewed the southern part
of this licence which surrounds the
Alton Field and oil in Permian reservoirs
such as at Bellbird and Cockatoo 1.
There are two principal targets for
exploration in ATP 2028 B; the 200,000
barrel Mardi lead to the west of Alton
in the Jurassic age Boxvale Sandstone
and the Triassic age Showgrounds
Sandstone in channels up dip from oil
in Farawell 1 where they drape over the
Farawell Nose Lead.
These
targets provide additional
potential to be explored in parallel with
oil production from prospects in Alton
and Eluanbrook.
Surat Basin (North)
Gas / Condensate Development
Downlands PL 441 – Bounty 100%, Spring Grove PCA 159 (ATP 1190) – Bounty 24.75%
Location: 2 km north of Surat Township Queensland
11
Bounty Oil & Gas NL Annual Report – 2019
Background
Downlands, in which Bounty had a minority interest, Bounty 100% ownership from AGL acquired in 2014. The re-
availability of the Silver Springs – Wallumbilla pipeline for gas export during this year coincided with the renewal of
the production lease which had been held up due to native title claims. In late 2018 these claims were deemed to
have been extinguished and PL 441 was renewed in June 2019. Bounty is determining feasibility.
2019/20 Operations
Work is underway on taking the gas wells and plant out of care and maintenance and bringing the field back to
production. During 2020 it is intended to produce the field and evaluate the potential reserves remaining. The
Downlands gas field occurs in sands overlying a basement high. Ringing the high where the sands about the basement
are a series of oil pools and potential pools in the Tinowan Formation, which were intersected in one well - Downlands-
3 - which produced oil to surface. Bounty intends to evaluate these oil pools further once the gas-condensate field is
back in production.
Western Australia - Carnarvon Basin
PL L16 - Bounty 100%
Location: Surrounding Rough Range Oil Field, 60 km south of Exmouth, WA
12
Bounty Oil & Gas NL Annual Report – 2019
Background
This licence straddles the Rough Range anticline, the location of the first oil discovery in Australia. The Dingo
Claystone, the prime source rock for the Carnarvon Basin, is mature and generating oil in the Patterson Trough running
north south along the western edge of the Licences. Oil has migrated a short distance into Rough Range Anticline.
Bounty's lands contain two known pools- Rough Range and Parrot Hill. Attempts to pursue further development of
these pools has been frustrated by pervasive faulting and poor seismic imaging along the crest of structures.
Future Work
The principal undrilled prospect is the 3
million bbl potential Bee Eater prospect in
the southern section of L 16.
Operations on this permit are partly
dependent on finding a suitable method to
image the reservoir section. Bounty is fully
reviewing the seismic and geological
database seeking methods to image oil
pools directly given the relatively shallow
1100 metre depth to target.
Growth Projects
PEP 11 - Offshore Sydney Basin, New South Wales – Bounty 15%
Background
PEP 11 covers 4,576 km2 of the offshore Sydney Basin immediately adjacent to the largest gas market in Australia and
is a high impact exploration project.
PEP 11 remains one of the
most significant untested
gas plays in Australia. The
PEP JV has demonstrated
gas
considerable
generation and migration
in the offshore Sydney
Basin, with the previously
mapped
observed
prospects and leads being
highly prospective for gas.
2018/19 Exploration
During the year Bounty
and the Operator - Asset
Energy Pty. Ltd. – resolved
outstanding issues related
to the Baleen 2D Seismic Survey and Bounty and Asset are now moving to a drill ready status. The operator supported
by Bounty cancelled a 3D seismic farmin option.
13
Bounty Oil & Gas NL Annual Report – 2019
AC/P 32 – Offshore Vulcan Sub-basin, Ashmore and Cartier
Territory - Bounty 100%
Location: Offshore 500 Km west of Darwin, NT.
Background
This permit is located within the Vulcan Sub-basin. In 2012
Bounty acquired a 100% interest in the permit and in June
2014 it was renewed for a further five years with a well
commitment in Year 2 and Year 5 if needed. The principal
target is the Azalea Prospect a 500 MMboip potential pool
with recoveries in the 20 - 40% range.
Bounty obtained an extension to the licence term from NOPTA to enable more definitive studies of the potential fluid
content of the Azalea Prospect and during the period negotiated to acquire the long offset modern 3D seismic data
recently acquired by Polarcus over the permit. However, efforts at farmout continued without success and Bounty is
currently reviewing this project.
Bounty Oil and Gas NL – Group Petroleum Reserves and Resources - at 30 June 2019
The Group has reviewed all Reserves and Resources to comply with Chapter 5 of the ASX listing rules, the result is
presented net to Bounty as at 30 June 2019:-
Discovered3
Producing4
Naccowlah1
Total Producing
Contingent5
Alton Shut In1
Alton Attic1
Downlands Gas Field1
Downlands Oil Leg2
Eluanbrook2
Naccowlah1
Spring Grove2
Total Contingent
Total Discovered
Undiscovered Prospective6
Surat (Mardi Prospect)2
AC/P 322
PEP 112
Total Undiscovered
MMboe7 (Recoverable)
1P
0.049
0.049
1C
0.048
0.020
0.101
0.021
0.189
0.238
Low
0.08
20
10.7
30.8
2P
0.104
0.104
2C
0.048
0.168
0.360
0.340
0.143
0.065
0.347
1.471
1.574
Best
0.21
113
128.8
242.0
3P
0.226
0.226
3C
0.048
0.168
0.360
0.340
0.197
0.242
0.347
1.702
1.928
High
0.42
302
128.8
431.2
14
Bounty Oil & Gas NL Annual Report – 2019
Method / Notes
1.
2.
3.
4.
5.
6.
7.
Deterministic Estimates – based on actual measurements of a petroleum reservoir and contained
petroleum.
Probabilistic Estimates (P90 ≡ 1P, P50 ≡ 2P, P10 ≡ 3P) – in probabilistic maths the solution or outcome
is a prediction with uncertainties that can be measured using chance or probability.
Drilled and proven moveable oil or gas
Discovered oil which is on production including nearby undeveloped oil
Discovered oil or gas whose commercial worth is contingent upon signing sales contract, production
testing and proving economic viability, shut in petroleum awaiting renewal of permit, or zones
adjacent to Discovered oil requiring further appraisal drilling
Specific targets for exploration based on volume estimation from seismic surveys and based on untested
models for hydrocarbon generation, migration and entrapment.
Converted at the rate of 182 boe = 1 MMcfg
Material Changes: Material changes from the prior period are:
1.
2.
3.
4.
2P Producing reserves up by 28% in year ended 30 June 2019 due to successful drilling in Naccowlah
Block SE Queensland.
Overall proved 2C resources are down due to withdrawal from Killiwani North Project.
Discovered Reserves and Contingent resources net of Killiwani are up 3% year on year due to successful
drilling in Naccowlah Block SE Queensland.
Undiscovered Prospective Resources are down 10% due to withdrawal from Nyuni Project, Tanzania.
15
Bounty Oil & Gas NL Annual Report – 2019
CORPORATE GOVERNANCE STATEMENT
Bounty Oil and Gas NL’s Corporate Governance Statement is on its website www.bountyoil.com and has been
released to the ASX.
DIRECTORS’ REPORT
Your directors present their report on the consolidated entity Bounty Oil & Gas NL (“Bounty”, “company” or “the
group”) being the company and its controlled entities for the financial year ended 30 June 2019.
Directors
The names of the directors in office at any time during or since the end of the financial year are:-
•
•
•
G. C. Reveleigh
C. Ross
R. Payne
(Chairman)
(Non-executive Director)
(Non-executive Director)
Company Secretary
The following persons held the position of company secretary and chief financial officer of the group during the
financial year:
•
S. Saraf
Principal Activities
The principal activity of the company and the group during the financial year was that of exploration for,
development, production and marketing of oil and gas (petroleum). Investment in listed entities is treated as a
secondary activity and business segment.
There were no significant changes in the nature of the company’s principal activities during the financial year.
Operating Results
Consolidated loss of the group attributable to equity holders after providing for income tax amounted to $2.78
million (see comparative details below).
Profit/(loss) from ordinary activities before
income tax
Income tax attributable to loss
Net profit/(loss) after income tax
Consolidated
2019
$ million
(2.78)
-
(2.78)
Consolidated
2018
$ million
(2.08)
-
(2.08)
Revenue from continuing operations for the period was up 130% on the previous year (2018:
$1.6 million) primarily due to a material increase in oil production and related sales in Australia.
The operating loss was determined after taking into account the following material items:
16
Bounty Oil & Gas NL Annual Report – 2019
•
•
•
•
Petroleum revenue; (mainly from oil and gas sales) of $3.66 million
Direct petroleum operating expenses of $1.47 million
Employee benefits expense of $0.59 million
Non-cash expenses for:
o
Impairment charge to oil and gas assets of
o Amortisation and depreciation expenses of
$3.16 million
$0.69 million
Details of drilling activity, exploration and development operations and cash flows for the year ended 30 June 2019
have been reported by the company to the Australian Securities Exchange in the Quarterly Activity Report and
Appendix 5B for each of the quarters during the year and in additional announcements on particular items.
A summary of revenues and results of significant business and geographical segments is set out in Note 4 to the
Financial Statements. Brief details are set out below:
Review of Operations
Production & Sales:
During the year ended 30 June 2019, the company:
•
Produced oil as a joint venture participant from several oil fields and leases operated by Santos Limited in ATP
1189P, Naccowlah Block, SW Queensland.
Petroleum revenue and production in barrels of oil equivalent (boe) are summarised below:-
Naccowlah Block
Bounty Share
(2% interest)
Totals
Revenue $
Production boe
2019
2018
$3.66 million
39,792
$1.57 million
13,162
Exploration and Development
Significant exploration and development operations during the year under review were:
Australia
Onshore
Cooper Basin, South-western Queensland
ATP 1189P Naccowlah Block; SW Queensland:
Oil production operations continued at an increased rate from the producing fields including Jackson and from wells
including recent wells in the Irtalie East, Watson, Watson North and Watkins Fields. New pipelines and production
infrastructure were completed. Australian $ oil prices remained attractive and cost cutting efforts continued. New
drilling is planned for later in 2019.
Further Later Development Plans were lodged with the Department of Natural Resources Mines and Energy for the
Naccowlah Block ATP 1189P Petroleum Leases and lease renewals were issued.
The operator Santos Limited undertook further near field exploration (NFE) and development drilling in the 12
months ending 30 June 2019 and Bounty participated in all wells with the following results:-
17
Bounty Oil & Gas NL Annual Report – 2019
Well
Wallis 1
Wenda 1 NFE
Cooroo NW 2
Results
Cased for production
P & A
Cased for production
Pallano East 1
P & A
Jarrar 5
Jarrar 4
Cased for production
Cased for production
Watson North 2
Cased for production
Watson North 3
Cased for production
Watkins 4
Watkins 5
Watkins 6
Cased for production
Cased for production
P & A
As a result of drilling in 2018 the Naccowlah Block 2P reserves increased 25% in the 2018 calendar year. Bounty
anticipates that the above 2019 drills will lift 2P reserves in 2019. After the period Bounty also participated in a
further oil discovery with the Tennaperra 9 well and further drills are planned for late 2019.
Surat Basin; Eastern Queensland
•
•
•
•
•
Petroleum Lease 2 Alton: Further planning is underway to develop these reserves in 2019/2020 initially by
producing oil from Alton Oilfield.
Bounty group now holds 100% of the Alton Oilfield, 100% of the Alton JV Block and 81.75%% of the Kooroon
JV all within PL 2 Alton.
As a result Bounty group is holding in the Alton Oilfield; development reserves of 167,000 bbls of recoverable
oil in the early Triassic age Basal Evergreen sand reservoir plus a potential 1.136 million bbls of 2P reserves
located in the three sands of the Boxvale/Evergreen Formations.
And an estimated recoverable resource of 186,000 bbls from P50 OOIP of 625,000 bbls in the Middle Triassic
age Showgrounds Sandstone reservoir at the Eluanbrook Prospect within that part of PL2 known as the
Kooroon JV.
Following commencement of planned oil production in late 2019 Bounty will continue development of these
resources.
Petroleum Lease 441 Downlands
•
•
During the period; PL 441 (formerly PL 119) covering shut in gas reserves and oil prospects was renewed
following final determination that Native Title did not exist within the PL boundary and the renewal was
granted on 5 June 2019.
Bounty completed certain compliance audits and facilities studies on its gas processing plant and developed
an optimal plan for re-commencing gas production.
18
Bounty Oil & Gas NL Annual Report – 2019
ATP 2028P (formerly ATP 754P):
•
Bounty group as the operator of the ATP 2028 joint venture with Armour Energy (Surat Basin) Pty Ltd obtained
the grant of ATP 2028P covering the southern section of former ATP 754P. Armour has a seismic option aimed
at conducting a drill test of the Mardi Prospect to test for oil and gas in several zones down to the Permian age
sequence by 2020 in which Bounty group will be free-carried. If seismic surveys are positive then drilling of that
multi-zone test is planned for 2020.
Rough Range, Western Australia
•
•
During the period the group relinquished EP 43 and EP 357. It conducted well integrity tests on the Rough
Range 1B well in Petroleum Licence L 16 onshore Carnarvon Basin and other remediation at the Rough Range
Oilfield.
Bounty is planning a full seismic and geological review at L 16.
Offshore
PEP 11; New South Wales: Bounty 15% interest:
The operator Asset Energy Pty Limited undertook a 2D seismic survey in March 2018 and the permit is in good
standing. Control of the operator reverted to interests associated with Mr David Breeze and Bounty and Asset have
co-operated to advance to a drill test of the previously well-defined Baleen Prospect. With major gas supply issues
developing in eastern Australia; the operator has identified a new target at Baleen Prospect with AVO analysis of
seismic data.
AC/P 32 Ashmore Cartier Territory; Timor Sea: Bounty 100%
o
o
In 2012 Bounty acquired a 100% interest in the permit. The principal target is the Azalea Prospect a
500 MMbbl original oil in place potential pool with a recoverable oil estimate of 100 MMbbls.
In 2018 NOPTA granted an extension of the Year 1 to 3 program for Bounty to licence and interpret
252km2 of the Polarcus Cygnus 3D Survey Data to enable more definitive studies of the potential
fluid content of the Azalea Prospect based on the long offset modern data acquired over the area
by that new 3D survey. Activity to achieve a farm out continued during the period.
Other Properties
During the period, Bounty continued to fund exploration and development expenditure in connection with its other
operated and joint venture interests located in Queensland and South Australia and Western Australia. Bounty is
actively seeking additional projects.
Tanzania
Kiliwani North Development Licence
Due to material delays in receipt of revenue from TPDC under the Gas Sales Agreement (“GSA”) Bounty withdrew
from the Kiliwani North Development Licence JV and fully impaired its investment resulting in a net non-cash expense
of $1,056,825.
Nyuni PSA:
Further Bounty withdrew from the Nyuni PSA and has fully impaired its investment with a net non-cash expense of
$1,696,751.
19
Bounty Oil & Gas NL Annual Report – 2019
Corporate – Share Issues
During the year ended 30 June 2019 the company did not make any equity issues.
Dividends Paid or Recommended
No dividends have been paid or declared for payment for the year ended 30 June 2019 and no dividend is
recommended.
Financial Position
The net assets of the group reduced by $2.1 million in the period 1 July 2018 to 30 June 2019 as a result of non-cash
impairments on petroleum properties. The significant underlying movements resulted from the following items:
o
Impairment of oil and gas assets of
$3.16 million.
o Amortisation of production assets
$0.69 million.
o Exploration write offs
$ nil
At 30 June 2019 current assets were $1.47 million.
During the financial year the company invested:-
•
•
$ 0.94 million on petroleum development drilling, property acquisitions and in completions and surface
production facility upgrades mainly in ATP 1189P Naccowlah Block; Queensland to further exploit its existing
proved producing oil reserves and to increase its oil reserves.
$ 0.21 million in petroleum exploration projects and acquisitions in Australia as summarised in the Review of
Operations above.
The directors believe the company is in a stable financial position to expand and grow its current operations.
Significant Changes in State of Affairs
There have been no significant changes in the state of affairs of the company during the financial year.
Contingent liabilities and Contingent Assets
As at the date this report, there were no contingent assets or liabilities.
There was no litigation against or involving Bounty Oil & Gas N.L. or its subsidiaries.
Events after the Reporting Period
No matters or circumstances have arisen since the end of the financial year which have significantly affected or may
significantly affect the operations of the company, the results of those operations, or the state of affairs of the
company in future financial years.
Future Developments, Prospects and Business Strategies
Subject to the amount of its ongoing oil and gas revenues and the availability of new capital; consistent with that
income and the available cash reserves of the group, Bounty will continue:
•
•
•
Production, development and exploration for oil and natural gas (petroleum).
Expand in the business of the exploration for, development of and production of petroleum.
To conduct such operations principally in Australia.
20
Bounty Oil & Gas NL Annual Report – 2019
In the coming year the group will focus on the:-
•
•
•
•
Development of its existing oil and gas reserves in the Cooper Basin and in the Surat Basin, Queensland aimed
at increasing group oil and gas revenue;
Financing and if successful preparing to drill its major offshore oil and gas targets in PEP 11, Sydney Basin and in
AC/P32, Timor Sea;
Acquisition of additional petroleum properties with existing petroleum production or reserves and resources
considered to have potential to develop and/or produce petroleum within an acceptable time frame;
Development of new business opportunities including other overseas projects.
Environmental regulations or Issues
The company’s operations are subject to significant environmental regulation under the law of the Commonwealth
of Australia and its States and Territories in respect of its operated and non-operated interests in petroleum
exploration, development and production. Its oil and gas production interests in the State of Queensland are
operated by Bounty group companies, AGL Energy Limited, Armour Energy (Surat Basin) Pty Ltd and Santos Limited
who comply with all relevant environmental legislation. Its offshore exploration operations in AC/P 32 Timor Sea are
conducted by the company in full compliance with all relevant environmental legislation of the Commonwealth of
Australia. Its non-operated offshore operations in PEP 11, NSW are similarly conducted by Asset Energy Pty Ltd a
competent operator. It complies with all relevant environmental legislation.
Information on Directors
The names and particulars of the directors of the company during or since the end of the financial year ended 30
June 2019, are:-
Graham Reveleigh
Qualifications
Experience
Special responsibilities:
Charles Ross
Qualifications
Experience
— Non-Executive Director
— BSc. MSc, M. Aus IMM.
— Mr Reveleigh is a professional geologist and has nearly 50 years’ experience in the
resources industry both in Australia and overseas. Early in his career, he worked in
the oil industry, then spent most of his career in exploration, mine management
and construction in the mineral industry. Mr Reveleigh has had extensive
experience in petroleum in recent years as a director of Drillsearch Energy Limited
and its Canadian subsidiary. He is a Member of the Australasian Institute of Mining
and Metallurgy and a member of the Petroleum Exploration Society of Australia.
He was appointed a director and chairman in 2005.
Chairman of the company; geotechnical advice.
— Non-Executive Director
— BSc.
Mr Ross has had extensive experience in the private and public equity and
corporate finance market in Canada, USA and Europe for 25years. He has operated
extensively in corporate asset acquisition and divestiture, review and development
of corporate financing strategies, administration, compliance procedures and
investor relations in North America and the Euro zone. He was a director of
Circumpacific Energy Corporation (a subsidiary of Drillsearch Energy Limited) from
1992 until 2008. This required management involvement in most aspects of
petroleum exploration, development and production operations in the Western
Canada Basin and other areas. He was appointed a director in 2005.
Special responsibilities:
Audit reviews; corporate strategy.
21
Bounty Oil & Gas NL Annual Report – 2019
Roy Payne
Qualifications
Experience
— Non-Executive Director
—
Solicitor Queensland.
Mr Payne is a commercial lawyer with over 34 years’ experience. Prior to working
in private practice as a lawyer he worked for the Department of Justice’,
Queensland for 14 years.
Mr Payne has many years of experience in the corporate world. He has been the
chairman of a listed mining exploration company. He is currently the chairman of
the board of a private ship maintenance and repair company and was the chairman
and director for many years of two limited liability, not for profit companies that
operate a public art gallery and a gallery foundation. He has a wealth of knowledge
and experience with corporate governance and mining exploration.
Special responsibilities:
Commercial law and Queensland statutory compliance.
Directorships of other listed companies
Directorships of other listed companies currently held by the directors or held in the 3 years immediately before the
end of the financial year are as follows:
Name
Company
Period of directorship
Mr G. Reveleigh
Pure Alumina Ltd (formerly Hill End Gold Limited)
1 July 2016 to present
Mr C. Ross
TSX Listed Companies; Canada:
Goldex Resources Corporation, Norzan Enterprises Ltd.,
Halio Energy Inc; Tearlach Resources Limited; Schwabo
Capital Corporation and Four Nines Gold Inc.
1 July 2016 to present
Mr R. Payne
Nil
Directors shareholdings
NA
The following table sets out each Directors interest in shares and options over shares of the Company or a related
body corporate as at the date of this report:-
Mr G. Reveleigh
Mr C. Ross
Mr R. Payne
Meetings of Directors/Committees
Bounty Oil & Gas NL
Fully paid ordinary shares
Number
Share options
Number
23,377,928
3,200,000
-
-
-
-
During the financial year, eleven (11) meetings of directors were held. Attendances by each director during the year
were as follows:-
Directors’ Meetings
Number eligible to attend
Number attended
Mr G. Reveleigh
Mr C. Ross
Mr R. Payne
11
11
11
11
11
11
The company does not have separate audit or remuneration committees.
22
Bounty Oil & Gas NL Annual Report – 2019
Indemnifying Officers or Auditor
During the financial year ended 30 June 2019 the company has not entered indemnity and access deeds with any of
the directors indemnifying them against liabilities incurred as directors, including costs and expenses in successfully
defending legal proceedings. The company has not, during or since the financial year, in respect of any person who
is or has been an auditor of the company or a related body corporate indemnified or made any agreement for
indemnifying against a liability incurred as an auditor, including costs and expenses in successfully defending legal
proceedings.
The company has paid premiums to insure each of the directors and officers in office at any time during the financial
year against liabilities up to a limit of $10 million for damages and for costs and expenses incurred by them in
defending any legal proceedings arising out of their conduct while acting in the capacity of director of the company,
other than conduct involving a wilful breach of duty in relation to the company.
Share Options
All options over ordinary shares or securities of Bounty Oil & Gas NL issued in a prior period have lapsed
unexercised. No options were issued during the year ending 30 June 2019 or have since been issued up to the date
of this report.
Accordingly at balance date on 30 June 2019 and at the date of this report, no unissued ordinary shares or securities
of Bounty Oil & Gas NL or any other entity comprising the consolidated entity were under option. No ordinary shares
of the company were issued pursuant to exercise of options during the year ending 30 June 2019
Legal Matters or Proceedings on Behalf of Company
No person has applied for leave of Court to bring proceedings on behalf of the company or intervene in any
proceedings to which the company is a party for the purpose of taking responsibility on behalf of the company for all
or any part of those proceedings.
The company was not a party to any such proceedings during the reporting period.
Non-Audit Services
The independent auditor to the company; Mr William Moyes has not provided non-audit services to the company
during or after the end of the financial year.
Remuneration of Directors and Management
Information on the remuneration of directors and other key management personnel is contained in the
Remuneration Report which forms part of this Directors Report and is set out on the following pages.
Auditor’s Independence Declaration
The auditor’s independence declaration for the year ended 30 June 2019 has been received and can be found on
Page 15.
Signed in accordance with a resolution of the Board of Directors made pursuant to s. 298(2) of the Corporations Act
2001.
On behalf of the Directors.
GRAHAM REVELEIGH
Chairman
Dated: 30 September 2019
23
Bounty Oil & Gas NL Annual Report – 2019
REMUNERATION REPORT
This remuneration report forms part of the Directors Report for the year ended 30 June 2019 and details the nature
and amount of remuneration for the Bounty Oil & Gas NL non-executive directors and other key management
personnel of the group.
The prescribed details for each person covered by this report are detailed below under the following headings:
• Director and senior management details
• Remuneration policy
• Non-executive directors policy
•
• Remuneration of directors and key management
•
Senior management personnel policy
Key terms and employment contracts
Directors and Key Management details
The term “key management” as used in this remuneration report to refers to the following directors and executives.
Directors
The following persons acted as directors of the company during or since the end of the financial year:-
• Mr G. C. Reveleigh
• Mr C. Ross
• Mr R. Payne
(Chairman)
(Non-Executive Director)
(Non-Executive Director)
Executives
The following persons acted as senior management of the company during or since the end of the financial year:
• Mr P. F. Kelso
(Chief Executive Officer)
The company does not consider other employees and consultants to be Key Management Personnel.
Remuneration policy
The remuneration policy of Bounty Oil & Gas NL has been designed to align key management personnel objectives
with shareholder and business objectives by providing a fixed remuneration component and bonuses issued at the
discretion of the board of the company. The board of Bounty Oil & Gas NL believes the remuneration policy to be
appropriate and effective in its ability to attract and retain the best key management personnel to run and manage
the company, as well as create goal congruence between directors, executives and shareholders.
All remuneration paid to key management personnel (directors and others) is valued at the cost to the company and
expensed or where appropriate transferred to capital items. Shares issued to key management personnel are
valued as the difference between the market price of those shares and the amount paid by the key management
person. Share options are valued using the Black- Scholes methodology. Shares and options granted to key
management personnel (directors and others) are subject to any necessary approvals required by the ASX Listing
Rules.
Performance-based remuneration
Given the long-term nature of and risk variables involved in exploration and development of petroleum resource
projects as compared to other sectors e.g. retail revenues; remuneration of directors or other key management
personnel is not performance based.
24
Bounty Oil & Gas NL Annual Report – 2019
Non-executive directors’ policy
The board policy is to remunerate non-executive directors at market rates for time, commitment and
responsibilities. The maximum aggregate amount of fees that can be paid to non-executive directors is within the
maximum amount specified in the company's Constitution. Any increase of that amount is subject to approval by
shareholders at the Annual General Meeting. Fees for non-executive directors are not linked to the performance of
the company.
Remuneration of non-executive directors is determined by the Board exclusive of the director under consideration
after considering the individual time commitment, duties and function of the subject Director. Further
considerations of the amount of remuneration are made by referral to amounts paid to Directors, both executive
and non-executive, by other listed entities of comparable size to the Company in the oil and gas exploration
industry.
The board of directors as a whole determines the proportion of any fixed and variable compensation for each other
key management person.
Any consulting fees payable to Directors as to specific projects outside the normal day to day duties of the Directors
are agreed upon prior to commencement of work on the specific projects.
The company makes cash bonus payments to key directors from time to time. Bonus payments by way of share
based payments are made from time to time subject to any necessary shareholder approval. All such payments are
expensed at the time of issue at the prevailing market price.
Each director is paid in cash. Shares and share options have on occasions been granted to directors as part of their
remuneration.
Senior management personnel policy
The board's policy for determining the nature and amount of remuneration of key management personnel who are
senior management executives of the company is as follows:-
The remuneration structure comprises a combination of, short term benefits including base fees and long-term
incentives and is based on a number of factors, including length of service, particular experience of the individual
concerned, and overall performance of the company. The contracts for service between the company and key
executive management personnel are for fixed terms which may continue at the end of the term. There were no
provisions for retirement benefits in contracts with senior management executives of the company made or
continued during the year ended 30 June 2019.
The company may make cash bonus payments to senior management executives and to selected employees from
time to time. Bonus payments and long-term incentives by way of share-based payments are classed as long-term
incentives and are made from time to time subject to any necessary shareholder approval. All such payments are
expensed at the time of issue at the prevailing market price.
Key management personnel who are employees receive a superannuation guarantee contribution required by the
government and do not receive any other retirement benefits. Some individuals, however, have chosen to sacrifice
part of their salary to increase payments towards superannuation.
The chief executive officer, Mr P. F. Kelso, is engaged through a fixed term service agreement with a personally
related entity containing the following material conditions:
• Management fees of $398,000 per annum payable by equal monthly instalments.
•
•
•
•
Payment of lease fees for a motor vehicle and parking.
Escalation of fees of 3% from 1 July 2019.
Bonuses at the discretion of the board of directors and there are no retirement or other fixed benefits.
The personally related entity is responsible for all statutory entitlements.
25
Bounty Oil & Gas NL Annual Report – 2019
•
Services: To include non-exclusive executive management, capital raising, communication, management
strategy, budgets, investment policy and all other duties normally incidental to the position of chief
executive officer.
Other than the directors and the chief executive officer, at the date of this Report all other personnel are permanent
or part time employees of the company and not classified as key management personnel.
Key Management Remuneration
Details of the remuneration of directors and the other key management personnel of the group (as defined in AASB
124 Related Party Disclosures) and the one highest paid executive of Bounty Oil & Gas N.L. are set out in the
following tables.
Key Management Remuneration
2019
Key Management Person
Short-term Benefits
$
Cash, salary and
commissions
Consulting
Fees + Other
Cash bonus
and Non-
cash
benefits (2)
Post-
employment
Benefits
Super-
annuation
Share based
payment
Total
Options
Non-Executive Directors
Mr G. Reveleigh (1)
Mr C. Ross (1)
Mr R. Payne
Other Key Management
Personnel – Chief Executive
officer
Mr P.F. Kelso (1)
60,000
30,000
-
-
-
-
-
7,652
-
-
-
20,000
398,000
5,765
8,400
-
-
-
-
-
60,000
37,652
20,000
412,165
1.
2.
Paid to a personally related entity of the director/executive.
Compensation for the 2019 financial year as set out in this column included only non-cash benefits of $5,765
Key Management Remuneration
2018
Key Management Person
Short-term Benefits
$
Cash, salary and
commissions
Consulting
Fees + Other
Cash bonus
and Non-
cash
benefits (4)
Post-
employment
Benefits
Super-
annuation
Share based
payment
Total
Options
Non-Executive Directors
Mr G. Reveleigh (3)
Mr C. Ross (3)
Mr R. Payne
Other Key Management
Personnel – Chief Executive
officer
Mr P.F. Kelso (3)
60,000
30,000
-
-
-
-
-
-
-
-
-
20,000
398,000
11,237
8,400
-
-
-
-
-
60,000
30,000
20,000
417,637
1.
2.
Paid to a personally related entity of the director/executive.
Compensation for the 2018 financial year as set out in this column included only non-cash benefits of $11,237.
No director or senior management person appointed during the above periods received a payment as part of his
consideration for agreeing to be appointed to that position.
26
Bounty Oil & Gas NL Annual Report – 2019
Share–based payments
During the financial year ended 30 June 2019 no share-based payments were made to Key Management Persons.
Fully paid ordinary shares
No fully paid ordinary shares were issued to Key Management Persons during the period.
Share Options
1. No share options were issued to directors or other key management persons or executives as part of their
remuneration during the year ended 30 June 2019 or since that date.
2. During the year, no directors or senior management held or exercised options that were granted to them as
part of their compensation in previous periods.
Loans to directors and executives
No loans were made to key management personnel including their personally related entities during the financial year
ended 30 June 2019 and no loans were outstanding at the end of the prior period. $15,000 due to the CEO for
acquisition of subsidiaries was paid during the year and the balance outstanding to his related entities at the time of
acquisition plus interest charge of 10% per annum stands at $113,360 at 30 June 2019.
Other Key Management Personnel Disclosures:
Further information on disclosure in connection with Key Management Personnel and Share Base Payments are set
out in the following Notes to the Financial Statements:-
1.
2.
3.
Note 19: Share Based Payments
Note 20: Key Management Personnel Disclosures
Note 22: Related Party Transactions.
Performance income as a proportion of total remuneration
The percentage of remuneration paid to directors and key management personnel during the financial year ended
30 June 2019 which was performance based was: Nil.
Employee Share Scheme
Bounty Oil & Gas N.L. has a current Employee Share Plan (the Plan) approved by shareholders.
Under the Plan all share issues to directors or other Key Management Personnel must receive prior shareholder
approval.
No ordinary shares of the company were issued under the Plan during the year ending 30 June 2019.
27
Bounty Oil & Gas NL
Annual Report – 2019
Consolidated statement of profit and loss and other comprehensive income
for the year ended 30 June 2019
Petroleum revenue
Net Investment income
Other income
Direct petroleum operating expense
Changes in inventory
Employee benefits and contractor expense
Depreciation expense
Amortisation of oil producing assets
Occupancy expense
Corporate activity costs
Rehabilitation finance costs
Foreign exchange gain/(loss)
Impairment of oil and gas assets
Exploration expenses write off
General legal and professional costs
Other expenses
Loss before Tax
Income tax expense
Loss for the period from continuing operations
Loss for the year
Other comprehensive income for the year, net of income tax
Total Comprehensive loss for the period
Year-ended
Notes
30-Jun-19
$
30-Jun-18
$
5
5
5
5
6
14
3,656,692
(3,466)
3,571
(1,469,689)
66,219
(598,236)
(68,263)
(733,259)
(103,852)
(284,597)
(27,849)
35,767
(3,161,710)
-
(47,797)
(46,099)
1,572,593
10,068
6,462
(943,419)
10,173
(721,562)
(45,366)
(422,492)
(105,715)
(48,423)
(25,015)
90,806
(1,382,853)
(1,373)
(35,100)
(39,102)
(2,782,568)
(2,080,318)
7
-
-
(2,782,568)
(2,080,318)
(2,782,568)
(2,080,318)
-
-
(2,782,568)
(2,080,318)
Total comprehensive income/(loss) attributable to owners of the parent
(2,782,568)
(2,080,318)
Earnings/(loss) per share
Basic (cents per share)
Diluted (cents per share)
(0.30)
(0.30)
(0.22)
(0.22)
The above consolidated statement of comprehensive income should to be read in conjunction with the accompanying
notes.
29
Bounty Oil & Gas NL
Annual Report – 2019
Consolidated statement of financial position
as at 30 June 2019
Assets
Current assets
Cash and cash equivalents
Trade and other receivables
Inventories
Other current financial assets
Total current assets
Non-current assets
Other receivables
Exploration and evaluation assets
Production and development assets
Property, plant and equipment
Total non-current assets
Total assets
Liabilities
Current liabilities
Trade and other payables
Provisions
Total current liabilities
Non-current liabilities
Unearned revenue
Provisions
Total non-current liabilities
Total liabilities
Net assets
Equity
Issued capital
Reserves
Retained losses
Equity attributable to owners of the parent
Total equity
Notes
30-Jun-19
$
30-Jun-18
$
9
10
11
12
10
14 (b)
14(a)
13
15
16
16
17
813,870
561,723
54,289
43,580
1,473,462
60,850
7,871,281
5,041,992
848,607
541,124
1,870,546
20,229
45,816
2,477,715
19,972
9,758,171
5,939,819
854,573
13,822,730
16,572,535
15,296,192
19,050,250
872,847
45,535
918,382
1,867,404
34,708
1,902,112
-
1,332,305
1,332,305
2,944
1,317,121
1,320,065
2,250,687
3,222,177
13,045,505
15,828,073
43,440,163
201,600
(30,596,258)
13,045,505
43,440,163
201,600
(27,813,690)
15,828,073
13,045,505
15,828,073
The above consolidated statement of financial position should to be read in conjunction with the accompanying notes.
30
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9
Bounty Oil & Gas NL
Annual Report – 2019
Consolidated statement of cash flows
for the year ended 30 June 2019
Cash flows from operating activities
Receipts from petroleum operations
Payments to suppliers and employees
Interest and dividend received
Year-ended
Notes
30-Jun-19
$
30-Jun-18
$
5,085,186
(3,625,726)
3,267
1,140,669
(1,498,769)
4,825
Net cash generated by/(used in) operating activities
18
1,461,497
(353,275)
Cash flows from investing activities
Payments for exploration and evaluation assets
Payments for oil production & development assets
Payments for property plant and equipment
Payments for acquisition of subsidiaries
Other deposits
Proceeds from sale of available-for-sale financial assets
Payment for available for sale financial assets
Net cash (used in) investing activities
Net increase/(decrease) in cash and cash equivalents
Cash and cash equivalents at the beginning of the period
Effects of exchange rate changes on the balance
of cash held in foreign currencies
Cash and cash equivalents at the end of the period
(238,093)
(879,386)
(29,483)
(15,000)
(40,878)
52,905
(54,135)
(1,204,070)
257,427
(13,882)
(127,169)
(1,950)
(258)
-
-
(10,809)
(154,068)
(507,343)
541,124
1,024,462
9
15,319
813,870
24,005
541,124
The above consolidated statement of cash flow should be read in conjunction with the accompanying notes.
32
Bounty Oil & Gas NL
Annual Report – 2019
Contents of the notes to the consolidated financial statements
1. Statement of compliance
2. Summary of significant accounting policies
3. Critical accounting estimates and judgments
4. Segment Information
5. Revenue and other income
6. Employee benefit expense
7. Income tax expense
8. Earnings/(loss) per share
9. Cash and cash equivalents
10. Trade and other receivables
11. Inventories
12. Other current financial assets
13. Property, plant and equipment
14. Non current assets
15. Trade and other payables
16. Provisions
17. Issued capital
18. Reconciliation of cash flow from continuing operations
19. Share based payments
20. Key management personnel
21. Commitments
22. Related party transactions
23. Financial instruments
24 . Controlled entities
25. Interest in joint operations
26. Parent entity information
27. Contingent liabilities and contingent assets
28. Events occurring after the reporting period
29. Auditors remuneration
30. Company details
33
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
1. Statement of compliance
Bounty Oil and Gas N.L. Is a company incorporated in Australia and limited by shares which are publicly traded on the Australian
Securities Exchange.
This financial report includes the consolidated financial statements and notes of Bounty Oil & Gas NL (“parent entity”) and
controlled entities (“consolidated group” or “group”) and the Group’s interest in jointly controlled assets for the financial year
ended 30 June 2019. Supplementary financial information about the parent entity is disclosed in Note 26. The Financial
Statements are presented in Australian currency.
The group is a for-profit entity for financial reporting purposes under Australian Accounting Standards.
The financial report was authorised for issue by the directors on 27 September 2019.
The financial report is a general purpose financial report that has been prepared in accordance with Australian Accounting
Standards, Australian Accounting Interpretations, other authoritative pronouncements of the Australian Accounting Standards
Board (AASB), and the Corporations Act 2001 .
Compliance with AASB 101 ensures compliance with International Financial Reporting Standard IAS 1 Presentation of Financial
Statements.
Australian Accounting Standards set out accounting policies that the AASB has concluded would result in a financial report
containing relevant and reliable information about transactions, events and conditions to which they apply. Compliance with
Australian Accounting Standards ensures that the financial statements and notes also comply with International Financial Reporting
Standards. Material accounting policies adopted in the preparation of this financial report are presented below. They have been
consistently applied unless otherwise stated.
2. Summary of significant accounting policies
a. Basis of preparation
The consolidated financial statements have been prepared on the basis of historical cost, except for the revaluation of certain non-
current assets and financial instruments. Cost is based on the fair values of the consideration given in exchange for assets. All
amounts are presented in Australian dollars, unless otherwise noted.
The financial report is presented in Australian dollars and under the option available to the Group under ASIC Corporations
(Rounding in Financial/Directors’ Reports) Instrument 2016/191, all values are rounded to the nearest dollar unless otherwise
stated.
The following significant accounting policies have been adopted in the preparation and presentation of the financial
reports. These accounting policies are consistent with Australian Accounting Standards and with International Financial Reporting
Standards.
b. Adoption of new and amended Accounting Standards
None of the new standards and amendmends to standards that are mandatory for the first time for the financial year beginning 1
July 2018 affected any of the amounts recognised in the current period or any prior period and are not likely to affect future
periods.
AASB 2014-10 Amendments to Australian Accounting Standards – Sale or Contribution of Assets between an Investor
and its Associates or Joint Venture
AASB 2016-5 Amendments to Australian Accounting Standards – Classification and Measurement of Share-based
Payment Transactions
AASB Interpretation 22 Foreign Currency Transactions and Advance Consideration
AASB 2018-2 Amendments to Australian Accounting Standards – Further Annual Improvements 2014-2017 Cycle
AASB 2017-2 Amendments to Australian Accounting Standards – Further Annual Improvements 2014-2016 Cycle
AASB 15 Revenue from Contracts with Customers
This standard supersedes AASB 111 Construction Contracts, AASB 18 Revenue and related Interpretations and it applies, with
limited exceptions, to all revenue arising from contracts with its customers. AASB 15 establishes a five-step model to account for
revenue arising from contracts with customers and requires that revenue be recognised at an amount that reflects the
consideration to which an entity expects to be entitled in exchange for transferring goods or services to a customer. AASB 15
requires entities to exercise judgement, taking into consideration all of the relevant facts and circumstances when applying each
step of the model to contracts with their customers. In addition, the standard requires extensive disclosures. The adoption of AASB
15 had no material impact on the Group and no transition adjustments to the comparative year.
34
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
b. Adoption of new and amended Accounting Standards (continued)
AASB 9 Financial Instruments
AASB 9 has been adopted from 1 July 2018. AASB 9 sets out requirements for recognising and measuring financial assets,
financial liabilities and some contracts to buy or sell non-financial items. AASB 9 largely retains the existing requirements of
AASB 139 for the classification and measurement of financial liabilities, however, it eliminates the previous AASB 139
categories for financial assets held to maturity, receivables and available for sale. Under AASB 9, on initial recognition a
financial asset is classified as measured at:
- Amortised cost;
- Fair Value through Other Comprehensive Income (FVOCI) – debt investment;
- FVOCI – equity investment; or
- Fair Value through Profit or Loss (FVTPL)
The new impairment model requires the recognition of impairment provisions based on expected crerdit lossess (ECL) rahter
than only incurred credit lossses. No adjustment was required to opening retained earnings at 1 July 2018 on transition to the
forwards looking ECL model. The Group has not applied hedge accounting in the current or prior years.
b. Accounting standards and interpretations issued but not yet effective
At the date of authorisation of the financial statements, the Standards and Interpretations listed below were in issue but not
yet effective or early adopted by the Group. There will be no material impact on the Group.
Title
Application date for the
Standard
Application date for the
Group
- AASB 16 Leases
- AASB Interpretation 23 Uncertainty over Income Tax Treatments
- AASB 2017-6 Amendments to Australian Accounting Standards –
Prepayment Features with Negative Compensation
- Conceptual Framework AASB 2019-1 Conceptual Framework for
Financial Reporting Amendments to Australian Accounting Standards –
- AASB 2018-7 Amendments to Australian Accounting Standards –
1 Jan 2019
1 Jan 2019
1 Jan 2019
1 Jan 2020
1 Jan 2020
1 July 2019
1 July 2019
1 Jan 2019
1 Jan 2020
1 Jan 2020
c. Basis of consolidation
(i) Controlled entities
The consolidated financial statements incorporate the assets, liabilities and results of entities controlled by Bounty Oil & Gas
NL at the end of the reporting period. A controlled entity is any entity over which Bounty Oil & Gas NL has the power to
govern the financial and operating policies so as to obtain benefits from the entity’s activities. Control will generally exist
when the parent owns, directly or indirectly through subsidiaries, more than half of the voting power of an entity. In assessing
the power to govern, the existence and effect of holdings of actual and potential voting rights are also considered.
Where controlled entities have entered or left the Group during the year, the financial performance of those entities are
included only for the period of the year that they were controlled. A list of controlled entities is contained in Note 24 to the
financial statements.
In preparing the consolidated financial statements all inter-group balances and transactions between entities in the
consolidated group have been eliminated on consolidation. Accounting policies of subsidiaries have been changed where
necessary to ensure consistency with those adopted by the parent entity.
For the reporting period the only controlled entities that Bounty Oil & Gas NL had were Ausam Resources Pty Limited (100%),
Interstate Energy Pty Limited (100%), Rough Range Pty Limited (100%) and Lansvale Oil & Gas Pty Ltd (100%).
35
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
c. Basis of consolidation (continued)
(ii) Joint arrangements
Under AASB 11 'Joint Arrangements' investments in joint arrangements are classified as either joint operations or joint
ventures depending on the contractual rights and obligations each investor has, rather than the legal structure of the joint
arrangement. Bounty Oil & Gas NL has assessed the nature of its joint arrangements and determined them to be joint
Bounty Oil & Gas NL has recognised its share of jointly held assets, liabilities, revenues and expenses of joint operations. These
have been incorporated in the financial statements under the appropriate headings. Details of the joint operations are set out
in note 25.
(iii) Business combinations
The Group applies the acquisition method in accounting for business combinations. The consideration transferred by the
Group to obtain control of a subsidiary is calculated as the sum of the acquisition-date fair values of assets transferred,
liabilities incurred and the equity interests issued by the Group, which includes the fair value of any asset or liability arising
from a contingent consideration arrangement. Acquisition costs are expensed as incurred.
The Group recognises identifiable assets acquired and liabilities assumed in a business combination regardless of whether
they have been previously recognised in the acquiree’s financial statements prior to the acquisition. Assets acquired and
liabilities assumed are generally measured at their acquisition-date fair values.
Goodwill is stated after separate recognition of identifiable intangible assets. It is calculated as the excess of the sum of: (a)
fair value of consideration transferred, (b) the recognised amount of any non-controlling interest in the acquire, and (c)
acquisition-date fair value of any existing equity interest in the acquiree, over the acquisition-date fair values of identifiable
net assets. If the fair values of identifiable net assets exceed the sum calculated above, the excess amount (i.e., gain on a
bargain purchase) is recognised in profit or loss immediately.
d. Interests in joint operations
A joint operation is a joint arrangement whereby the parties that have joint control of the arrangement have rights to the
assets, and obligations for the liabilities, relating to the arrangement. Joint control is the contractually agreed sharing of
control of an arrangement, which exists only when decisions about the relevant activities require unanimous consent of the
parties sharing control.
When a group entity undertakes its activities under joint operations, the Group as a joint operator recognises in relation to its
interest in a joint operation:
• its assets, including its share of any assets held jointly;
• its liabilities, including its share of any liabilities incurred jointly;
• its share of the revenue from the sale of the output by the joint operation; and
• its expenses, including its share of any expenses incurred jointly.
The Group accounts for the assets, liabilities, revenues and expenses relating to its interest in a joint operation in accordance
with the AASBs applicable to the particular assets, liabilities, revenues and expenses. When a group entity transacts with a
joint operation in which a group entity is a joint operator (such as a sale or contribution of assets), the Group is considered to
be conducting the transaction with the other parties to the joint operation, and gains and losses resulting from the
transactions are recognised in the Group's consolidated financial statements only to the extent of other parties' interests in
the joint operation.
e. Income tax
The income tax expense / (income) for the year comprises current income tax expense / (income) and deferred tax expense
(income).
Current income tax expense charged to the profit or loss is the tax payable on taxable income calculated using applicable
income tax rates enacted, or substantially enacted, as at reporting date. Current tax liabilities (assets) are therefore measured
at the amounts expected to be paid to (recovered from) the relevant taxation authority.
Deferred income tax expense reflects movements in deferred tax asset and deferred tax liability balances during the year as
well unused tax losses.
Deferred tax assets and liabilities are ascertained based on temporary differences arising between the tax bases of assets and
liabilities and their carrying amounts in the financial statements. Deferred tax assets also result where amounts have been
fully expensed but future tax deductions are available. No deferred income tax will be recognised from the initial recognition
of an asset or liability, excluding a business combination, where there is no effect on accounting or taxable profit or loss.
Current and deferred income tax expense / (income) is charged or credited directly to equity instead of the profit or loss when
the tax relates to items that are credited or charged directly to equity.
36
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
e. Income tax (continued)
Deferred tax assets and liabilities are calculated at the tax rates that are expected to apply to the period when the asset is
realised or the liability is settled, based on tax rates enacted or substantively enacted at reporting date. Their measurement
also reflects the manner in which management expects to recover or settle the carrying amount of the related asset or
Deferred tax assets relating to temporary differences and unused tax losses are recognised only to the extent that it is
probable that future taxable profit will be available against which the benefits of deferred tax asset can be utilised.
Where temporary differences exist in relation to investments in subsidiaries, branches, associates, and joint ventures, deferred
tax assets and liabilities are not recognised where the timing of the reversal of the temporary difference can be controlled and
it is not probable that the reversal will occur in the foreseeable future.
Current tax assets and liabilities are offset where a legally enforceable right of set-off exists and it is intended that net
settlement or simultaneous realisation and settlement of the respective asset and liability will occur. Deferred tax assets and
liabilities are offset where a legally enforceable right of set-off exists, the deferred tax assets and liabilities relate to income
taxes levied by the same taxation authority on either the same taxable entity or different taxable entities where it is intended
that net settlement or simultaneous realisation and settlement of the respective asset and liability will occur in future periods
in which significant amounts of deferred tax assets or liabilities are expected to be recovered or settled.
Tax Consolidation - Bounty Oil & Gas NL and its wholly owned Australian subsidiary have not formed an income tax
consolidation group under tax consolidation legislation. Each entity in the Group recognises its own current and deferred tax
assets and liabilities. Such taxes are measured using the ‘stand alone taxpayer’ approach to allocation.
f. Going concern basis
The directors have prepared the financial report on a going concern basis, which contemplates the continuity of normal
business activities and the realisation of assets and the settlement of liabilities in the ordinary course of business.
For the period ended 30 June 2019, the Group realised a net loss after tax of $2,782,568 (2018: $2,080,318). This was largely
as a result of non-cash impairment of $3.16 million to oil and gas assets. The net cash generated by operating activities for the
period ended 30 June 2019 was $1,461,497 (2018: net cash utilised $353,275). The Group’s net asset position at 30 June 2019
was $13,045,505 (30 June 2018: $15,828,073) and its cash balance amounted to $813,870 (30 June 2018: $541,124).
The directors’ cash flow forecasts project that the group will continue to be able to meet its liabilities and obligations
(including those exploration commitments as disclosed in Note 21) as and when they fall due for a period of at least 12 months
from the date of signing of this financial report. The cash flow forecasts are dependent upon the generation of sufficient cash
flows from operating activities to meet working capital requirements; contemplating issue of additonal equity by the Group;
the ability of the Group to manage discretionary exploration and evaluation expenditure on non-core assets via farmout or
disposal of certain interests and or a reduction in its future work programmes. The directors are of the opinion that the use of
the going concern basis of accounting is appropriate as they are satisfied as to the ability of the Group to implement the
g. Fair value measurement
AASB 13 establishes a single source of guidance for determining the fair value of assets and liabilites. AASB 13 does not change
when an entity is required to use fair value, but rather, provides guidance on how to determine fair value when fair value is
required or permitted. Application of this definition may result in different fair values being determined for the relevant
assets. AASB 13 also expands the disclosure requirements for all assets and liabilites carried at fair value. This includes
information about the assumptions made and the qualitative impact of those assumptions on the fair value determined.
Consequential amendmends were also made to other standards.
AASB 13 requires the disclosure of fair value information by level of the fair value hierarchy, which categorises fair value
measurements into one of three possible levels based on the lowest level that a significant input to the measurement can be
categorised into as follows:
- level 1: Measurement based on quoted prices (unadjusted) in active markets for identical assets or liabilities that the entity
can access at the measurement date.
-level 2: Measurements based on inputs other than quoted prices included in level 1 that are observable for the asset or
liability, either directly or indirectly.
-level 3: Measurements based on unobservable inputs for the asset or liability.
The carrying values of financial assets and liabilites recorded in the financial statements approximates their respective fair
values, determined in accordance with the acounting policies described above and adjusted for capitalised transaction costs, if
any.
37
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
h. Trade and other receivables
Trade receivables are recognised initially at fair value and subsequently measured at amortised cost, less provision for
doubtful debts. Trade receivables are due for settlement no more than 30 days.
Collection of trade receivables is reviewed on an ongoing basis. Debts, which are known to be uncollectible, are written off. A
provision for doubtful receivables is established when there is objective evidence that the Group will not be able to collect all
amounts due according to the original terms of receivables. The amount of the provision is the difference between the asset’s
carrying amount and the present value of estimated future cash flows, discounted at the original effective interest rate. Cash
flows relating to short-term receivables are not discounted if the effect of discounting is immaterial. The amount for the
provision is recognised in the income statement.
i. Property, plant and equipment
Each class of property, plant and equipment is carried at cost or fair value as indicated less, where applicable, any
accumulated depreciation and impairment losses.
Any accumulated depreciation at the date of revaluation is eliminated against the gross carrying amount of the asset and the
net amount is restated to the revalued amount of the asset.
Plant and equipment are measured on the cost basis.
The carrying amount of plant and equipment is reviewed annually by directors to ensure it is not in excess of the recoverable
amount from these assets. The recoverable amount is assessed on the basis of the expected net cash flows that will be
received from the asset’s employment and subsequent disposal.
The cost of fixed assets constructed within the consolidated group includes the cost of materials, direct labour, borrowing
costs and an appropriate proportion of fixed and variable overheads.
Subsequent costs are included in the asset’s carrying amount or recognised as a separate asset, as appropriate, only when it is
probable that future economic benefits associated with the item will flow to the Group and the cost of the item can be
measured reliably. All other repairs and maintenance are charged to the income statement during the financial period in
which they are incurred.
j. Depreciation
The depreciable amount of all fixed assets including buildings and capitalised lease assets, but excluding freehold land, is
depreciated on a straight-line basis over the asset’s useful life to the Group from the time the asset is held ready for use.
Leasehold improvements are depreciated over the shorter of either the unexpired period of the lease or the estimated useful
lives of the improvements.
Depreciation on assets is calculated over their estimated useful life as follows:
Class of fixed asset
Office furniture and fittings
Computer equipment
Plant and equipment
Estimated useful life
5 years
4 years
5 years
The assets’ residual values and useful lives are reviewed, and adjusted if appropriate, at each balance sheet date.
An asset’s carrying amount is written down immediately to its recoverable amount if the asset’s carrying amount is greater
than its estimated recoverable amount.
Gains and losses on disposals are determined by comparing proceeds with the carrying amount. These gains and losses are
included in the income statement. When re-valued assets are sold, amounts included in the revaluation reserve relating to
that asset are transferred to retained earnings.
k. Exploration and evaluation expenditure
Exploration and evaluation expenditures in relation to each separate area of interest are recognised as an exploration and
evaluation asset in the year in which they are incurred where the following conditions are satisfied:
• the rights to tenure of the area of interest are current; and,
• at least one of the following conditions is also met:
i) the exploration and evaluation expenditures are expected to be recouped through successful exploration, development and
commercial exploitation of the area of interest, or alternatively, by its sale; or,
ii) exploration and evaluation activities in the area of interest have not, at the reporting date, reached a stage which permits a
reasonable assessment of the existence or otherwise of economically recoverable petroleum reserves or resources and active
and significant operations in, or in relation to, the area of interest are continuing.
38
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
k. Exploration and evaluation expenditure (continued)
Exploration and evaluation assets are initially measured at cost and include acquisition of rights to explore, geophysical
surveys, studies, exploratory drilling, sampling and associated activities and an allocation of depreciation and amortisation of
assets used in exploration and evaluation activities. General and administrative costs are only included in the measurement
of exploration and evaluation costs where they are related directly to operational activities in a particular area of interest.
Exploration and evaluation assets are assessed for impairment when facts and circumstances suggest that the carrying
amount of an exploration and evaluation asset may exceed its recoverable amount. The recoverable amount of the
exploration and evaluation asset (or the cash-generating unit(s) to which it has been allocated, being no larger than the
relevant area of interest) is estimated to determine the extent of the impairment loss (if any). Where an impairment loss
subsequently reverses, the carrying amount of the asset is increased to the revised estimate of its recoverable amount, but
only to the extent that the increased carrying amount does not exceed the carrying amount that would have been determined
had no impairment loss been recognised for the asset in previous years. Where a decision is made to proceed with
development in respect of a particular area of interest, the relevant exploration and evaluation asset is tested for impairment
and the balance is then re-classified to development.
l. Production and development assets
The group follows the full cost method of accounting for production and development assets whereby all costs, less any
incentives related to the acquisition, exploration and development of oil and gas reserves are capitalised. These costs include
land acquisition costs, geological and geophysical expenses, the costs of drilling both productive and non productive wells,
non producing lease rentals and directly related general and administrative expenses. Proceeds received from the disposal of
properties are normally credited against accumulated costs.
When a significant portion of the properties is sold, a gain or loss is recorded and reflected in profit or loss.
With respect to production assets, depletion of production and development assets and amortisation of production facilities
and equipment are calculated using the unit of production method based on estimated proven oil and gas reserves. For the
purposes of depletion calculation proved oil and gas reserves before royalties are converted to a common unit measure.
The estimated costs for developing proved underdeveloped reserves, future decommissioning and abandonments, net of
estimated salvage values, are provided for on the unit of production method included in the provision for depletion and
amortisation.
In applying the full cost method of accounting, the capitalised costs less accumulated depletion are restricted from exceeding
an amount equal to the estimated discounted future net revenues, based on year end prices and costs, less the aggregate
estimate future operating and capital costs derived from proven and probable reserves.
Development expenditure is recognised at cost less accumulated amortisation and any impairment losses. Where commercial
production in an area of interest has commenced, the associated costs together with any forecast future capital expenditure
necessary to develop proved and probable reserves are amortised over the estimated economic life of the field on a units-of-
production basis.
Changes in factors such as estimates of proved and probable reserves that affect unit of production calculations are dealt with
on a prospective basis.
m. Trade and other payables
These amounts represent liabilities for goods and services provided to the Group prior to the end of the financial year, which
are unpaid. The amounts are unsecured and are usually paid within 30 days of recognition.
n. Inventories
Inventories are measured at the lower of cost and net realisable value. Net realisable value is the estimated selling price in the
ordinary course of business less any estimated selling costs. The cost of petroleum products includes direct materials, direct
labour and an appropriate portion of variable and fixed overheads.
o. Leases
Leases are classified at their inception as either operating or finance leases based on the economic substance
of the agreement so as to reflect the risks and benefits incidental to ownership.
Operating leases
A lease where a significant portion of the risks and rewards of ownership are retained by the lessor are classified as operating
leases. Payments in relation to operating leases are charged to the income statement on a straight-line basis over the period
of the lease.
39
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
p. Financial instruments
i) Financial assets at fair value through profit or loss
A financial instrument is any contract that gives rise to a financial asset of one entity and a financial liability or equity
instrument of another entity.
Initial recognition and measurement
Financial assets are classified, at initial recognition, as subsequently measured at amortised cost, fair value through other
comprehensive income (OCI), and fair value through profit or loss. The classification of financial assets at initial recognition
depends on the financial asset’s contractual cash flow characteristics and the Group’s business model for managing them.
With the exception of trade receivables that do not contain a significant financing component or for which the Group has
applied the practical expedient, the Group initially measures a financial asset at its fair value plus, in the case of a financial
asset not at fair value through profit or loss, transaction costs. Trade receivables that do not contain a significant financing
component or for which the Group has applied the practical expedient are measured at the transaction price determined
under AASB 15. In order for a financial asset to be classified and measured at amortised cost, it needs to give rise to cash flows
that are solely payments of principal and interest on the principal amount outstanding. This assessment is referred to as the
SPPI test and is performed at an instrument level. The Group’s business model for managing financial assets refers to how it
manages its financial assets in order to generate cash flows. The business model determines whether cash flows will result
from collecting contractual cash flows, selling the financial assets, or both. Purchases or sales of financial assets that require
delivery of assets within a time frame established by regulation or convention in the market place are recognised on the trade
date(the date that the Group commits to purchase or sell the asset).
Subsequent measurement
For purposes of subsequent measurement, financial assets are classified in following categories:
(i) Financial assets at amortised cost (debt instruments)
(ii) Financial assets at fair value through profit or loss
(iii) derecognition (equity instruments)
(i) Financial assets at amortised cost (debt instruments):
The Group measures financial assets at amortised cost if both of the following conditions are met:
- The financial asset is held within a business model with the objective to hold financial assets in order to collect contractual
cash flows and
- The contractual terms of the financial asset give rise on specified dates to cash flows that are solely
payments of principal and interest on the principal amount outstanding
Financial assets at amortised cost are subsequently measured using the effective interest (EIR) method and are subject to
impairment. Gains and losses are recognised in profit or loss when the asset is derecognised, modified or impaired.
The Group’s financial assets at amortised cost includes other receivables.
(ii) Financial assets at fair value through profit or loss:
Financial assets at fair value through profit or loss include financial assets held for trading, financial assets designated upon
initial recognition at fair value through profit or loss, or financial assets mandatorily required to be measured at fair value.
Financial assets are classified as held for trading if they are acquired for the purpose of selling or repurchasing in the near
term. Derivatives, including separated embedded derivatives, are also classified as held for trading unless they are designated
as effective hedging instruments. Financial assets with cash flows that are not solely payments of principal and interest are
classified and measured at fair value through profit or loss, irrespective of the business model.
Financial assets at fair value through profit or loss are carried in the statement of financial position at fair value with net
changes in fair value recognised in the statement of profit or loss.
(iii) Derecognition:
A financial asset (or, where applicable, a part of a financial asset or part of a group of similar financial assets) is primarily
derecognised (i.e., removed from the Group’s consolidated statement of financial position) when:
-The rights to receive cash flows from the asset have expired or
- The Group has transferred its rights to receive cash flows from the asset or has assumed an obligation to pay the received
cash flows in full without material delay to a third party under a ‘pass-through’ arrangement; and either (a) the Group has
transferred substantially all the risks and rewards of the asset, or (b) the Group has neither transferred nor retained
substantially all the risks and rewards of the asset, but has transferred control of the asset.
When the Group has transferred its rights to receive cash flows from an asset or has entered into a passthrough
arrangement, it evaluates if, and to what extent, it has retained the risks and rewards of ownership.
When it has neither transferred nor retained substantially all of the risks and rewards of the asset, nor transferred control of
the asset, the Group continues to recognise the transferred asset to the extent of its continuing involvement. In that case, the
Group also recognises an associated liability. The transferred asset and the associated liability are measured on a basis that
reflects the rights and obligations that the Group has retained.
40
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
p. Financial instruments (continued)
Continuing involvement that takes the form of a guarantee over the transferred asset is measured at the lower of the original
carrying amount of the asset and the maximum amount of consideration that the Group could be required to repay.
Impairment of financial assets
Expected credit losses (ECLs) for all debt instruments not held at fair value through profit or loss will be recognised through an
allowance. ECLs are based on the difference between the contractual cash flows due in accordance with the contract and all
the cash flows that the Group expects to receive, discounted at an approximation of the original effective interest rate. The
expected cash flows will include cash flows from the sale of collateral held or other credit enhancements that are integral to
the contractual terms.
ECLs are recognised in two stages. For credit exposures for which there has not been a significant increase in credit risk since
initial recognition, ECLs are provided for credit losses that result from default events that are possible within the next 12-
months (a 12-month ECL). For those credit exposures for which there has been a significant increase in credit risk since initial
recognition, a loss allowance is required for credit losses expected over the remaining life of the exposure, irrespective of the
timing of the default (a lifetime ECL). For trade receivables and contract assets, the Group applies a simplified approach in
calculating ECLs. Therefore, the Group does not track changes in credit risk, but instead recognises a loss allowance based on
lifetime ECLs at each reporting date.
The Group considers a financial asset in default when contractual payments are 90 days past due. However, in certain cases,
the Group may also consider a financial asset to be in default when internal or external information indicates that the Group is
unlikely to receive the outstanding contractual amounts in full before taking into account any credit enhancements held by
the Group. A financial asset is written off when there is no reasonable expectation of recovering the contractual cash flows.
ii) Financial liabilities
Initial recognition and measurement
Financial liabilities are classified, at initial recognition, as financial liabilities at fair value through profit or loss, loans and
borrowings, payables, or as derivatives designated as hedging instruments in an effective hedge, as appropriate.
The Group’s financial liabilities include trade and other payables.
Derecognition
A financial liability is derecognised when the obligation under the liability is discharged or cancelled or expires. When an
existing financial liability is replaced by another from the same lender on substantially different terms, or the terms of an
existing liability are substantially modified, such an exchange or modification is treated as the derecognition of the original
liability and the recognition of a new liability. The difference in the respective carrying amounts is recognised in the statement
of profit or loss.
Offsetting of financial instruments
Financial assets and financial liabilities are offset and the net amount is reported in the consolidated statement of financial
position if there is a currently enforceable legal right to offset the recognised amounts and there is an intention to settle on a
net basis, to realise the assets and settle the liabilities simultaneously.
q. Impairment of assets
Other assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount
may not be recoverable.
An impairment loss is recognised for the amount by which the asset’s carrying amount exceeds its recoverable amount. The
recoverable amount is the higher of an asset’s fair value less costs to sell and value in use. For the purpose of assessing
impairment, assets are grouped at the lowest levels for which there are separately identifiable cash inflows which are largely
independent of the cash inflows from other assets or groups of assets (cash-generating units). Non-financial assets other than
goodwill that suffered impairment are reviewed for possible reversal of the impairment at each reporting date.
r. Foreign currency
Functional and presentation currency
The functional currency is measured using the currency of the primary economic environment in which the Group operates
(the “functional” currency). The financial statements are presented in Australian dollars which is the Group’s functional and
presentation currency.
Transactions and balances
Foreign currency transactions are translated into functional currency using the exchange rates prevailing at the date of the
transaction. Foreign currency monetary assets and liabilities are translated at the exchange rate at balance date. Non-
monetary items measured at historical cost continue to be carried at the exchange rate at the date of the transaction.
Exchange differences arising on the translation of monetary items are recognised in the income statement, except where
deferred in equity as a qualifying cash flow or net investment hedge.
41
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
s. Employee benefits
Wages and salaries,other entiltlements
Provision is made for the Group’s liability for employee benefits arising from services rendered by employees to balance date.
Employee benefits that are expected to be settled within one year have been measured at the amounts expected to be paid
when the liability is settled. Employee benefits payable later than one year have been measured at the present value of the
estimated future cash outflows to be made for those benefits. Those cash flows are discounted using market yields on
national government bonds with terms to maturity that match the expected timing of cash flows. Employee benefits payable
later than one year include Statutory Long Service Leave only.
Share based payments – employee share plan
Share based compensation has from time to time been provided to eligible persons via the Bounty Oil & Gas N.L. Employee
Share Plan (“Plan”). Under AASB 2 “Share-based Payments”, the Employee Share Plan shares are deemed to be equity-settled
share-based remuneration.
Equity-settled share-based payments with employees and others providing similar services are measured at the fair value of
the equity instrument at the grant date. Fair value is measured by use of the quoted market price or binomial pricing model.
The fair value determined at the grant date of the equity-settled share-based payments is expensed on a straight-line basis
over the vesting period, based on the Group’s estimate of equity instruments that will eventually vest, with a corresponding
increase in equity.
t. Provisions
Provisions are recognised when the Group has a legal or constructive obligation, as a result of past events, for which it is
probable that an outflow of economic benefits will result and that outflow can be reliably measured. Provisions are
determined by discounting the expected future cash flows at a pre-tax discount rate that reflects current market assessments
of the time value of money and, where appropriate, the risks specific to the liability.
u. Cash and cash equivalents
Cash and cash equivalents include cash on hand, deposits held at call with banks, other short-term highly liquid investments
with original maturities of three months or less, and bank overdrafts.
v. Rehabilitation obligations
Provisions for future environmental restoration are recognised where there is a present obligation as a result of exploration,
development, production or storage activities having been undertaken and it is probable that an outflow of economic benefits
will be required to settle the obligation. The estimated future obligations include the costs of removing facilities, abandoning
wells and restoring the affected areas.
The provision for future restoration costs is the best estimate of the present value of the expenditure required to settle the
restoration obligation at the reporting date. Future restoration costs are reviewed annually and any changes in the estimate
are reflected in the present value of the restoration provision at reporting date, with a corresponding charge in the cost of the
associated asset.
The amount of the provision for future restoration costs relating to exploration, development and production facilities is
capitalised and depleted as a component of the cost of those activities.
The unwinding of the effect of discounting on the provision is recognised as a finance cost.
w. Revenue and other income
Revenue is measured at the fair value of the consideration received or receivable after taking into account any trade discounts
and volume rebates allowed. Any consideration deferred is treated as the provision of finance and is discounted at a rate of
interest that is generally accepted in the market for similar arrangements. The difference between the amount initially
recognised and the amount ultimately received is interest revenue.
Revenue from the sale of goods is recognised at the point of delivery as this corresponds to the transfer of significant risks and
rewards of ownership of the goods and the cessation of all involvement in those goods.
Interest revenue is recognised using the effective interest rate method, which, for floating rate financial assets, is the rate
inherent in the instrument. Dividend revenue is recognised when the right to receive a dividend has been established.
All revenue is stated net of the amount of goods and services tax (GST).
x. Goods and services tax (GST)
Revenues, expenses and assets are recognised net of the amount of GST, except where the amount of GST incurred is not
recoverable from the Australian Tax Office. In these circumstances the GST is recognised as part of the cost of acquisition of
the asset or as part of an item of the expense. Receivables and payables in the balance sheet are shown inclusive of GST.
Cash flows are presented in the cash flow statement on a gross basis, except for the GST component of investing and financing
activities, which are disclosed as operating cash flows.
42
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
y. Earnings per share
The Group presents basic and diluted earnings per share (“EPS”) for its ordinary shares.
Basic EPS is calculated by dividing the profit attributable to equity holders of the Company by the weighted number of shares
outstanding during the period.
Diluted EPS is determined by adjusting the profit or loss attributable to ordinary shareholders and the weighted average
number of ordinary shares outstanding for the effects of all potential ordinary shares, which compriseshare options issued.
z. Comparative figures
When required by Accounting Standards, comparative figures have been adjusted to conform to changes in presentation for
the current financial year.
aa. Contributed equity
Ordinary shares are classified as equity. Incremental costs directly attributable to the issue of new shares or options are
shown in equity as a deduction from the proceeds.
3. Critical accounting estimates and judgments
In the application of the group’s accounting policies, which are described in Note 1, the directors are required to make
judgments, estimates and assumptions about the carrying amounts of assets and liabilities that are not readily apparent from
other sources. The estimates and associated assumptions are based on historical and industry experience and other factors
that are considered to be relevant. Actual results may differ from these estimates.
The estimates and underlying assumptions are reviewed on an ongoing basis. Revisions to accounting estimates are
recognised in the period in which the estimate is revised if the revision affects only that period or in the period of the revision
and future periods if the revision affects both current and future periods.
The following are the critical judgments that management has made in the process of applying the group’s accounting policies
and that have the most significant effect on the amounts recognised in the financial statements:
Business combination
Management uses valuation techniques in determining the fair values of the various elements of a business combination. See
Note 2(c)(iii).
Exploration and evaluation assets
The group’s policy is discussed in Note 2(k). The application of these policies requires management to make certain estimates
and assumptions as to future events and circumstances. Any such estimates and assumptions may change as new information
becomes available. If after having capitalised exploration and evaluation expenditure, management concludes that the
capitalised expenditure is unlikely to be recovered by future sale or exploitation, then the relevant capitalised amount will be
written off through profit or loss.
Estimate of reserve quantities
The estimated quantities of proven and probably hydrocarbon reserves and resources reported by the group are integral to
the calculation of amortisation (depletion) and depreciation expense and to assessments of possible impairment of assets.
Estimated reserve quantities are based upon data from exploration and development drilling, interpretations of geological
and geophysical models and assessment of the technical feasibility and commercial viability of producing the reserves.
Management prepares reserve estimates which conform to guidelines prepared by the Society of Petroleum Engineers, USA.
Where appropriate these estimates are then verified by independent technical experts.
These assessments require assumptions to be made regarding future development and production costs, commodity prices,
exchange rates and fiscal regimes. The estimates of reserves may change from period to period as the economic assumptions
used to estimate the reserves can change from period to period, and as additional geological or reservoir data is generated
during the course of operations.
Provision for rehabilitation and decommissioning
The group estimates the future removal and decommissioning costs of oil and gas production facilities, wells, pipelines and
related assets at the time of installation of the assets. In most instances the removal of these assets will occur many years in
the future. The estimates of future removal costs therefore requires management to make adjustments regarding the
removal date, future environmental legislation, the extent of decommissioning activities and future removal technologies.
43
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
Impairment of production and development assets
The group assesses whether oil and gas assets are tested for impairment on a semi-annual basis. This requires an estimation
of the recoverable amount from the cash generating unit to which each asset belongs. The recoverable amount is assessed on
the basis of the expected net cash flows that will be received from the asset’s employment and or subsequent disposal. The
expected net cash flows are discounted to their present values in determining the recoverable amount. Its policy for
production and development assets is discussed in Note 1(l).
During the year, the group carried out annual reviews of its petroleum production, development and exploration properties.
The reviews led to the recognition of an impairment loss of $3.17 million. As at 30 June 2019, Tanzanian Permits (Kiliwani
North/Nyuni Block) were fully impaired ($2.76 million). Other impairments were relinquished permits EP 359 and EP435
($0.41 million). Further commentary on impairment is included in the Directors' Report. This non-cash loss has been
recognised in the Group's profit or loss statement. These properties are reported as in the core oil and gas segment.
4. Segment Information
Identification of Reportable Segments
Information reported to the Chief Operating Decision Maker, being the CEO, for the purposes of resource allocation and
assessment of the performance is more specifically focused on the category of business units. The Group’s reportable
segments under AASB 8 Operating Segments are therefore as follows:
Core Petroleum Segment - Oil and gas exploration, development and production
Secondary Segment - Investment in listed shares and securities.
Segment revenue and results
Core Oil & Gas Segment
Production projects
Exploration projects
Secondary Segment
Listed securities
Total from continuing operations
Other revenue
Central admin costs and directors remuneration
Loss before tax
Segment revenue
Segment profit/(loss)
30-Jun-19
$
30-Jun-18
$
3,656,692
1,572,593
-
-
30-Jun-19
$
419,828
(2,104,885)
30-Jun-18
$
(1,095,362)
(117,226)
(3,466)
3,653,226
10,068
1,582,661
(3,466)
(1,688,523)
39,338
(1,133,383)
(2,782,568)
10,068
(1,202,520)
97,268
(975,066)
(2,080,318)
Segment revenue
Revenue reported above represents revenue/income generated from external sources. There were no intersegment sales
during the period (2018: nil).
Accounting policies of reportable segments
The accounting policies of the reportable segments are the same as the group’s accounting policies described in Note 1.
Segment profit/(loss) in this Note represents the profit/(loss) earned by each segment without allocation of central
administration costs and directors remuneration, other investment revenue such as interest earned, finance costs and
income tax expense. This is the measure reported to the Chief Operating Decision Maker for the purpose of resource
allocation and assessment of segment performance.
Information about major customers
Included in the revenue arising from direct sales of oil and gas of $3.66 million (2018: $1.57 million) are revenues of
approximately $2.44 million (2018: $0.81 million) which arose from sales to the Group’s largest customer. The revenue from
the Group’s second largest customer was approximately $1.22 million (2018: $0.35 million). No other single customer
contributed 10% or more to the Groups revenue for both 2019 and 2018.
Other segment information
Core Oil & Gas Segment
Production projects
Development projects
Exploration projects
Other
Total
Amortisation, depreciation
& depletion
Additions to non-current
assets
30-Jun-19
$
798,925
-
-
2,597
801,522
30-Jun-18
$
465,586
-
-
30-Jun-19
$
604,947
333,292
217,995
2,272
467,858
6,373
1,162,607
30-Jun-18
$
223,857
113,388
486,571
1,951
825,767
44
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
4. Segment Information (continued)
Core Oil & Gas Segment
Production projects
Exploration projects
Total
Impairment losses
(expenses)
30-Jun-19
$
1,056,825
2,104,885
3,161,710
30-Jun-18
$
1,267,000
117,226
1,384,226
Segment assets are measured in the same way as in the financial statements. These assets are allocated based on the
operations of the segment and the physical location of the asset.
Segment liabilities are allocated to segments where there is a direct nexus between the incurrence of the liability and the
operations of the segment. Segment liabilites incude trade and other payables and provisions.
The unallocated items include items that are not considered part of the core operations of any segment.
Core Oil & Gas Segment
Production projects
Development projects
Exploration projects
Secondary Segment
Listed securities
Unallocated
Total
Segment assets
Segment liabilities
30-Jun-19
$
4,914,253
1,544,826
7,871,281
30-Jun-18
$
5,575,835
1,211,534
9,758,171
30-Jun-19
$
1,411,083
172,649
75,961
30-Jun-18
$
2,800,274
8,734
23,796
43,580
922,252
15,296,192
45,816
2,458,894
19,050,250
-
590,994
2,250,687
-
389,373
3,222,177
Geographical Segment information
The following table details the group’s geographical segment reporting of revenue and carrying amount of assets in each
geographical region where operations are conducted.
Revenue
Carrying amounts of non
current assets
30-Jun-19
$
3,692,564
-
3,692,564
30-Jun-18
$
1,332,627
347,302
1,679,929
30-Jun-19
$
13,822,730
-
13,822,730
30-Jun-18
$
13,805,305
2,767,230
16,572,535
30-Jun-19
$
3,627,085
29,607
3,656,692
30-Jun-18
$
1,544,446
28,147
1,572,593
975
(4,441)
(3,466)
3,567
35,767
4
39,338
-
10,068
10,068
6,457
90,806
5
97,268
3,692,564
1,679,929
Australia
Tanzania
Total
5. Revenue and other income
Sales revenue:
Oil and gas sales
Revenue from tariffs
Total sales revenue
Investment income:
Investment income from financial assets at fair value through
Profit and loss (held for trading listed shares)
Realised gain
Unrealised gain/(loss)
Total investment income
Other income:
Interest income
Gains/(losses) on foreign currency
Other income
Total other revenue
Total revenue
45
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
6. Employee benefit expense
Directors fees
Consultancy fees - Internal
Wages & salaries
Other employee benefit expenses
Total Employee benefit expense
30-Jun-19
$
(31,927)
398,000
183,920
48,243
598,236
30-Jun-18
$
110,000
398,000
186,563
26,999
721,562
Directors fees were in credit for the year due to adjustment pf prior period accruals.
Recharge and recoveries
The Group has the policy to allocate a portion of employee benefit expense to production, development, exploration and
evaluation assets based on employee time committed to various projects.
7. Income tax expense
The prima facie tax on profit from ordinary activities before income tax is
reconciled to the income tax as follows:
Prima facie tax payable on profit/(income tax benefit) from continuing
operations before income tax at 27.5% (2018 27.5%)
Consolidated group
Add: tax effect of non deductible expenses
Less: tax effect of expenditure claimed as deduction
Tax effect of Unused tax losses not recognised as deferred tax asset
Income tax expense attributable to loss from ordinary activities
$
(765,205)
494,578
(20,080)
$
(572,087)
637,834
(303,980)
(290,707)
(238,233)
-
-
The potential future income tax benefit arising from tax losses and timing differences has not been recognised as an asset
because recovery of tax losses is not probable and recovery of timing differences is not assured beyond reasonable doubt.
The potential future income tax benefit will be obtained if:
1) the relevant company derives future assessable income of a nature and an amount sufficient to enable the benefit to be
realised, or the benefit can be realised by another company in the Group in accordance with Division 170 of the Income Tax
Assessment Act 1997;
2) the relevant company and/or group continues to comply with the conditions for deductibility imposed by the Act; and
3) no changes in tax legislation adversely affect the Company and/or the group in realizing the benefit.
Bounty Oil and Gas NL and its wholly-owned subsidiaries have not formed a tax consolidation group.
8. Earnings/(loss) per share
Basic earnings/(loss) per share (cents per share)
Diluted earnings/(loss) per share (cents per share)
(0.30)
(0.30)
(0.22)
(0.22)
Net (loss)/profit used in the calculation of basic and diluted earnings/(loss) per share
(2,782,568)
(2,080,318)
Weighted average number of ordinary shares for the purposes
of basic and diluted EPS
9. Cash and cash equivalents
Deposits on call
Cash at bank
Total Cash and cash equivalents
No. of Shares No. of Shares
953,400,982
953,400,982
$
64,547
749,323
813,870
$
63,479
477,645
541,124
46
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
10. Trade and other receivables
Current
Trade receivables
Prepayments
Other receivables
Acquisition through business combination
Non-current
Other receivables
Total trade and other receivables
11. Inventories
Oil and other inventory
12. Other current financial assets
Financial assets at fair value through profit and loss - shares in
listed corporations
Total current financial assets
Note
23(d)
13. Property, plant and equipment
Plant and Equipment
Plant and equipment – at cost
Less accumulated depreciation
Total Property, plant and equipment
Movement in carrying amounts:
Movements in the carrying amounts for each class of property, plant and
equipment between the beginning and end of the financial year.
Opening Balance
Additions
Acquisition through business combination
Depreciation
Carrying amount at the end of the year
30-Jun-19
$
496,643
3,926
61,154
-
30-Jun-18
$
1,859,171
3,926
2,086
5,363
60,850
622,573
19,972
1,890,518
$
54,289
54,289
$
20,229
20,229
$
$
43,580
43,580
45,816
45,816
$
$
1,179,827
(331,220)
1,117,531
(262,958)
848,607
854,573
$
$
854,573
62,297
-
(68,263)
848,607
559,403
40,536
300,000
(45,366)
854,573
47
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
14. Non current assets
Note
30-Jun-19
30-Jun-18
(a): Production and development assets
SW Queensland
Joint operation interest in ATP1189 Naccowlah Block – at cost
Less: Amortisation
East Queensland - PL 441 (ex-PL119) Downlands – at cost
Less: Depletion and amortisation
Nyuni Block, Tanzania- Kiliwani North
Joint operation interest in Nyuni Block - Kiliwani North at cost
Less: Amortisation
Less: Impairment
Rehabilitation costs – all petroleum properties
All other development assets
Total production and development assets
25
25
Movement in carrying amounts of production & development assets:
Opening balance at the beginning of the year
Additions
Movement in rehabilitation
Impairment of production and development assets (see i below)
Amortisation of production assets
Carrying amount at the end of the year
$
$
3,003,427
(1,505,000)
3,850,998
(2,518,609)
2,463,113
(815,000)
3,828,635
(2,518,609)
1,356,825
(300,000)
(1,056,825)
666,350
1,544,826
5,041,992
2,637,479
(300,000)
(1,267,000)
699,667
1,211,534
5,939,819
$
$
5,939,819
882,315
(33,317)
(1,056,825)
(690,000)
5,041,992
7,329,025
298,660
(70,866)
(1,267,000)
(350,000)
5,939,819
(i) In accordance with the Group's accounting policies and procedures, the Group performs its impairment testing at the end
of each reporting period. A number of factors represented indicators of impairment. As at 30 June 2019, Tanzanian Permits
(Kiliwani North/Nyuni Block) were fully impaired. Refer to table in note 14(c) below. Further commentary on impairment is
included in the Directors' Report. No other impairments were recognised for this reporting period.
Key assumptions used:
Crude oil price (US$)
Average AUD:USD exchange rate
CPI (%)
Post-tax real discount rate (%)
(b): Exploration and evaluation assets
Exploration assets
Total exploration and evaluation assets
2019-2020
$63.00
$0.700
2.0%
7.0%
25
Movement in carrying amounts of exploration and evaluation assets:
Opening balance at the beginning of the year
Additions
Acquisition through business combination
Impairment of Exploration and evaluation asset (see i above)
Carrying amount at the end of the year
(c): Impairment of oil and gas properties
Nyuni Block Tanzania - Kiliwani North
Nyuni Block Tanzania - Nyuni PSA
EP 359/EP 435 Rough Range
Bakersfield
2021+
$70.00
$0.75
2.0%
7.0%
$
$
7,871,281
7,871,281
9,758,171
9,758,171
$
$
9,758,171
217,995
-
(2,104,885)
7,871,281
9,688,826
90,634
95,937
(117,226)
9,758,171
$
$
1,056,825
1,696,751
408,134
-
1,267,000
-
-
115,853
48
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
15. Trade and other payables
Current
Trade payables
Trade payables acquired through business combination
Amounts owing to Joint Operations
GST, FBT, PAYG & superannuation liability
Total trade and other payables
16. Provisions
Current - Provision for employee entitlement
Non-current - Provision for employee entitlement
Non-current - Rehabilitation costs – petroleum properties
Movement in provisions
Opening balance
Unwinding of discount on provision
Net provisions recognised/(expensed)
Balance at the end of the period
30-Jun-19
30-Jun-18
$
$
297,579
-
493,861
81,407
872,847
$
45,535
22,935
1,309,370
1,332,305
1,317,121
27,849
(12,665)
1,332,305
203,627
121,280
1,542,136
361
1,867,404
$
34,708
9,827
1,307,294
1,317,121
1,290,528
25,015
1,578
1,317,121
The provision for rehabilitation costs represents the present value of best estimate of the future sacrifice of economic
benefits that will be required to remove the facilities and restore the affected areas at the Group’s operation sites. The
rehabilitation of the petroleum properties is expected to be undertaken between 1 to 20 years. The discount rate used in the
calculation of the provision as at 30 June 2019 was 2%, broadly equivalent to the Australian Government 10 year bond rate.
Long service leave is measured at the present value of benefits accumulated upto the end of financial year. The liability is
discounted using an appropriate discount rate. The measurement requires judgement to determine key assumptions used in
the calculation including futures pay increases and settlement dates of employee's departure.
17. Issued capital
A reconciliation of the movement in capital for the Company can be found in
the Consolidated Statement of Changes in Equity
953,400,982 fully paid ordinary shares (2018: 953,400,982)
Nil options transferred to share option reserve on expiry (2018: Nil)
(a) Movement in fully paid ordinary shares
Balance at beginning of period
Balance at end of period
$
$
43,440,163
201,600
43,641,763
43,440,163
201,600
43,641,763
No. of Shares No. of Shares
953,400,982
953,400,982
953,400,982
953,400,982
18. Reconciliation of cash flow from continuing operations
Reconciliation of Cash Flow from continuing operations with profit/(loss) after income tax.
Profit/(Loss) from continuing operations after income tax
$
$
(2,782,568)
(2,080,318)
Non-cash flows in profit/(loss) from continuing operations:
Unearned income on rental lease
Depreciation and amortisation
Fair value movement in marketable financial assets
Foreign exchange differences
Movement in employee benefit obligation
Impairment of receivables
Acquisition costs included in investing
Impairment and Write-off of exploration assets
Impairment of oil and gas assets
Accrued interest expense
Accrued interest income
Change in trade and other receivables
Profit/(loss) on sale of marketable financial assets
Change in inventory
Change in rehabilitation obligation
Change in trade & other payables
Net Cash from continuing operations
49
(2,944)
758,263
4,441
(10,925)
(101,645)
234,827
-
-
3,161,710
7,081
(304)
1,062,825
(975)
(34,060)
71,108
(905,337)
1,461,497
(2,944)
467,858
(10,068)
(97,252)
11,774
-
323
117,226
1,267,000
(1,636)
(554,453)
-
6,041
97,507
425,667
(353,275)
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
19. Share based payments
No share based payment compensation was granted to directors or senior management during the financial year ended 30th
June 2019 and there was Nil expensed (2018: Nil). During the year, no directors or senior management exercised options that
were granted to them as part of their compensation in prior periods.
20. Key management personnel
a) Key Management Personnel Compensation
The aggregate remuneration made to Key Management
Personnel of the group is set out below:
Short term employee benefits
Share based payments
Total
30-Jun-19
$
30-Jun-18
$
395,239
-
395,239
527,637
-
527,637
Apart from the details disclosed in this note, no director or key management person has entered into a material contract with
the consolidated entity since the end of the previous financial year and there were no material contracts involving directors’ or
executives’ interests existing at year-end.
Information regarding individual directors' and executives' compensation and some equity instrument disclosures as permitted
by the Corporations Regulations 2M.3.03 is provided in the Remuneration Report section of the Directors' Report.
b) Equity Instrument Disclosures Relating to Key Management Personnel
i) Options provided as remuneration and shares issued on exercise of such options: Nil
ii) Share holdings
The movement during the reporting period in the number of ordinary shares in Bounty Oil and Gas N.L. held, directly, indirectly
or beneficially, by each key management person, inculding related parties, is as follows:
2019
Directors
G Reveleigh
R Payne
C Ross
Executives
P Kelso
2018
Directors
G Reveleigh
R Payne
C Ross
Executives
P Kelso
Balance at Start
of the Year
Purchases
Received on
exercise of
Options
Received other
Sales
Held at the end
of Year
23,377,928
-
3,200,000
- - - 23,377,928
- - - -
- - - 3,200,000
-
-
50,979,133 849,153 - -
51,828,286
23,377,928
- - - 23,377,928
- - - - - -
3,200,000 - - - - 3,200,000
52,879,980 1,349,153 - - 3,250,000 50,979,133
No shares were granted to key management personnel during the financial year or during the previous financial year.
c) Key Management Personnel - other loans and advances
No loans were made to key management personnel including their personally related entities during the financial year ended 30
June 2019 and no loans were outstanding at the end of the prior period. $15,000 due to CEO for acquisition of subsidiaries was
paid during the year and the balance outstanding to his related entities at the time of acquisition plus interest charge of 10% per
annum stands at $113,360 at 30 June 2019.
50
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
20. Key management personnel (continued)
d) Other transactions with key management personnel
Other than the transactions disclosed in the Remuneration Report contained in the Directors’ Report, during the financial year,
$24,750 was paid for office rent, $8,400 for site management services and $15,000 towards consideration due for acquisition of
subsidiaries in previous year, to firms in which Mr. P. Kelso is a director.
Aggregate amounts of each of the above types of other transactions with entities associated with key management personnel
of Bounty Oil & Gas NL:
Payment towards consideration for acquisition of Rough Range Oil Pty Ltd.
Site management services for PL2
Rent of office
21. Commitments
30-Jun-19
$
15,000
8,400
24,750
48,150
30-Jun-18
$
-
8,400
33,000
41,400
In order to maintain current rights of tenure to its licences and permits, the company has certain obligations to perform work in
accordance with the work programmes, as approved by the relevant statutory body, when the permits are granted. These work
programs form the capital commitment which may be renegotiated, varied between permits, or reduced due to farm-out, sale,
reduction of permit/licence area and/or relinquishment of non-prospective permits. Work in excess of the work programs may
also be undertaken.
The following capital expenditure requirements have not been provided for in the accounts:
Payable
Not longer than 1 year
Longer than 1 year and not longer than 5 years
There are no lease commitments at the balance date.
22. Related party transactions
a. The Group’s main related parties are as follows:
$
767,004
1,917,510
2,684,514
$
1,776,833
4,442,082
6,218,915
Key Management Personnel
Any person(s) having authority or responsibility for planning, directing and controlling the activities of the Group, directly or
indirectly, including any director (whether executive or otherwise) of the Group are considered as key management personnel.
Disclosures relating to key management personnel are set out in Note 20 and in the Directors Report.
Controlled entities
Details of the percentage of ordinary shares held in controlled entities are disclosed in Note 24.
All inter-company loans and receivables are eliminated on consolidation and are interest free with no set repayment terms.
b. Transactions with other related parties:
The Group has a related party relationship with its joint ventures/joint operations (note 25) and with its key management
personnel. The Company and its controlled entities engage in a variety of related party transactions in the ordinary course of
business. These transactions are generally conducted on normal terms and conditions.
There were no transactions with related parties other than as disclosed in Note 20 and this Note 22.
23. Financial instruments
a) Capital management:
The Group manages its capital to ensure that entities in the Group will be able to continue as going concerns while maximising
the return to stakeholders. The Group’s overall strategy remains unchanged from last financial year.The Group's capital
structure consists of equity (comprising issued capital, reserves and retained earnings as detailed in Consolidated Statement of
Changes in Equity) and no debt. The Group is not subject to any externally imposed capital requirements.
The Board reviews the capital structure of the Group on an on-going basis. As part of this review, the Board considers the cost
of capital and associated risks.
The gearing ratio at the end of the reporting period was nil (2018: nil).
51
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
23. Financial instruments (continued)
b) Categories of financial instruments:
Financial assets
Cash and cash equivalents
Loans deposits and receivables
Available for sale financial assets designated as at FVTPL
Total financial assets
Financial liabilities
Other amortised cost - trade creditors
Total financial liabilities
Note
12
30-Jun-19
30-Jun-18
$
813,870
622,573
43,580
1,480,023
$
541,124
1,890,518
45,816
2,477,458
(872,847)
(872,847)
(1,867,404)
(1,867,404)
c) Financial risk management objectives:
The main risks the company is exposed to through its financial instruments are interest rate risk, foreign currency risk, liquidity
risk, credit risk and price risk.
Foreign currency risk:
Foreign currency risk is managed by retaining majority of its cash and payables in Australian currency. Petroleum sales are
received in USD with short term credit terms. The Group does not currently use derivative financial instruments to hedge
foreign currency risk and therefore is exposed to daily movements in exchange rates. However, the Group intends to maintain
sufficient USD cash balances to meet its USD obligations.
Liquidity risk:
The Group manages liquidity risk by maintaining adequate reserves and banking facilities by continuously monitoring forecast
and actual cash flows, and by matching the maturity profiles of financial assets and liabilities.
Credit risk:
Credit risk refers to the risk that a counter party will default on its contractual obligations resulting in a financial loss to the
Group and arises principally from the Group’s receivables from customers and cash deposits. The Group’s 2019 trade
receivables are deposits and amounts due from State government departments and major Oil & Gas companies in Australia.
There were past due receivables from Kiliwani Joint operations at 30 June 2018. The Group exited the joint operations during
the year and these receivables have now been adjusted against related payables, and balance fully impaired.
The Company does not have any material credit risk exposure to any single debtor or company of debtors under financial
instruments or collateral securities entered into by the Company.
Exposure to credit risk is monitored on an ongoing basis. The maximum exposure to credit risk is represented by the carrying
amount of each financial asset in the statement of financial position.
The carrying amount of the Group’s financial assets represents the maximum credit exposure. The Group’s maximum exposure
to credit risk at the reporting date was:
Carrying amount:
Cash and cash equivalents
Trade and other receivables
30-Jun-19
$
813,870
622,573
1,436,443
30-Jun-18
$
541,124
1,890,518
2,431,642
All cash held by the Group is deposited with investment grade banks and any expected credit loss is immaterial.
The aging of the Group’s trade receivables at reporting date was:
30-Jun-19
30-Jun-18
Past due
Not past due
Commodity risk:
The sales revenue of the company is derived from sales of oil at the prevailing TAPIS or Dated Brent oil price on the Singapore
market in USD. Sales volumes are not sufficient to undertake the expense of entering derivative contracts to manage that risk.
-
-
Gross $
Impairment
$
234,827 (234,827) 646,738
561,723 - 1,233,780
Gross $
Impairment
$
d) Fair value of financial instruments:
Some of the Group's financial assets and financial liabilities are measured at fair value at the end of each reporting period. The
following table gives information about how the fair values of these financial assets and financial liabilities are determined (in
particular, the valuation technique(s) and inputs used).
52
Bounty Oil & Gas NL
Notes to the consolidated financial statements
for the year ended 30 June 2019
Annual Report – 2019
d) Fair value of financial instruments (continued):
The fair values of financial assets and liabilities with standard terms and conditions and traded on active liquid markets are
determined with reference to quoted market prices. The fair values of other financial assets and financial liabilities are
determined in accordance with generally accepted pricing models based on discounted cash flow analysis.
Except as detailed in the following table, the directors consider that the carrying amounts of financial assets and financial
liabilities recognised in the consolidated financial statements approximate their fair values.
Consolidated
Fair value hierarchy
30-Jun-19
$
30-Jun-18
$
Financial assets at fair value
through profit or loss (see
note 12)
Quoted bid prices
in an active market
Level 1
43,580
45,816
e) Sensitivity analysis
The company does not perform sensitivity analysis with respect to interest rate risk, foreign currency risk, liquidity risk,
credit risk or price risk.
24 . Controlled entities
The consolidated financial statements incorporate the assets, liabilities and results of the following controlled
entities in accordance with the accounting policy described in note 2 (c)(i).
Name of entity
Ausam Resources Pty Ltd.
Interstate Energy Pty Ltd.
Rough Range Oil Pty Ltd.
Lansvale Oil & Gas Pty Ltd.
(1) The proportion of ownership interest is equal to the proportion of voting power held.
Class of shares
Ordinary
Ordinary
Ordinary
Ordinary
Australia
Australia
Australia
Australia
Equity holding % (1)
100
100
100
100
100
100
100
100
Country of Incorporation
30-Jun-19
30-Jun-18
25. Interest in joint operations
Set out below are the joint arrangements of the Group as at 30 June 2019, which in the opinion of the directors are material
to the Group:
Name of the joint
arrangement
ATP 1189P Naccowlah block
Nyuni PSA
Kiliwani North
ATP 2028P (ex-ATP 754P)
PEP11
Measurement
Method
Proportionate Adelaide, Australia
Proportionate Dar es Salaam, Tanzania
Proportionate Dar es Salaam, Tanzania
Proportionate Brisbane, Australia
Proportionate Perth, Australia
Principal
activity
Production
Exploration
Production
Exploration
Exploration
2%
6.666%*
10%
50%
15%
Ownership interest (%)
(*approx)
Principal place of
business
2%
-
-
50%
15%
The company holds 2% interest in various Petroleum Leases and part of ATP 1189P, Queensland and associated oil
production tangibles and pipelines referred to as the Naccowlah Block.
Details of the total revenue and expenses derived from or incurred in ATP 1189P joint operations and the company’s share
of the assets and liabilities employed in these joint operations are as follows:
Revenue from petroleum
Petroleum and all other expenses
Net Profit/(Loss) from joint operations
Current assets
Trade receivables
Inventories
Non current assets
Property, plant & equipment (net of accumulated depreciation)
Other non-current assets
Total assets in joint operations
Current liabilities - Trade and other payables
Non current liabilities - Provisions
Total liabilities in joint operations
Net interest in joint operations
53
30-Jun-19
$
30-Jun-18
$
3,656,692
(2,180,039)
1,476,653
1,572,593
(1,400,955)
171,638
524,990
54,289
1,823,959
20,229
515,605
2,164,777
3,259,661
493,861
1,047,790
1,541,651
1,718,010
502,533
3,418,259
5,764,980
1,432,481
1,062,806
2,495,287
3,269,693
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
25. Interest in joint operations (continued)
The Group’s joint operations agreements require majority consent from all parties for all relevant activities. The joint
participants own the assets of the joint operations as tenants in common and are jointly and severally liable for the liabilities
incurred by the joint operations. These entities are therefore classified as joint operations and the group recognises its direct
right to the jointly held assets, liabilities, revenues and expenses as described in note 2(c)(ii) & 2(d).
The accounting policies adopted for the group’s joint operations are consistent with those in previous financial year.
The company’s share of revenue and expenses from joint operations are included in the Consolidated Statement of
Comprehensive Income. The company’s share of the assets and liabilities held in joint operations are included in the
Consolidated Statement of Financial Position.
Interests in other joint operation entities
Also included in the Consolidated Financial Statements as at 30 June 2019, the group held interests in joint operations whose
principal activities were exploration, evaluation and development of oil and gas but not accruing material revenue.
The company contributes cash funds to the joint operations by way of cash calls for a specified percentage of total exploration
and development activities. Other than the ATP1189P Naccowlah Block production Joint Operations none of the joint
operations hold any material assets and accordingly the Company’s share of exploration, evaluation and development
expenditure is accounted for in accordance with the policy set out in Note 1.
26. Parent entity information
The accounting policies of the parent entity, which have been applied in determining the financial information shown below,
are same as those applied in the consolidated financial statements. Refer to Note 1 for a summary of the significant accounting
policies relating to the Group. After review of policies, the Board resolved to reclassify the intercompany loans to controlled
entities as non current assets.
The individual financial statements for the parent entity Bounty Oil & Gas NL show the following aggregate amounts:
Statement of Financial Position
Assets
Current assets
Non-current assets
Total Assets
1,378,875
14,920,323
16,299,198
2,366,392
17,581,371
19,947,763
30-Jun-19
$
30-Jun-18
$
Liabilities
Current liabilities
Non-current liabilities
Total Liabilities
Net Assets
Equity
Issued capital
Reserves
Retained earnings/Accumulated losses
Total Equity
Statement of Profit and Loss and other Comprehensive Income
Loss for the year
Other comprehensive income/(loss)
Total Comprehensive loss for the year
Commitments for Capital Expenditure
No longer than 1 year
Longer than 1 year and not longer than 5 years
Total
There are no operating lease commitments at the balance date.
54
795,880
1,112,368
1,908,248
14,390,950
1,777,004
1,110,250
2,887,254
17,060,509
43,440,163
201,600
(29,250,813)
14,390,950
43,440,163
201,600
(26,581,254)
17,060,509
(2,669,560)
(2,059,608)
-
-
(2,669,560)
(2,059,608)
683,004
1,707,510
2,390,514
1,501,833
3,754,583
5,256,416
Bounty Oil & Gas NL
Annual Report – 2019
Notes to the consolidated financial statements
for the year ended 30 June 2019
27. Contingent liabilities and contingent assets
As at the date this report, there were no contingent assets or liabilities.
There was no other litigation against or involving Bounty Oil & Gas N.L. or its subsidiaries.
28. Events occurring after the reporting period
No matters or circumstances have arisen since the end of the financial year which have significantly affected or may
significantly affect the operations of the company, the results of those operations, or the state of affairs of the company in
future financial years, other than those referred to in note 27 above.
29. Auditors remuneration
Remuneration of the auditors of the Company for:
- Auditing or reviewing the financial reports for year
- Other services
Total
30-Jun-19
30-Jun-18
$
30,000
-
30,000
$
26,500
-
26,500
The auditor to Bounty Oil & Gas NL is William M Moyes, Suite 1301, Level 13, 115 Pitt Street, Sydney NSW 2000.
30. Company details
Bounty Oil & Gas NL’s registered office and its principal place of business are as follows:
Registered Office
Suite 302, 93-95 Pacific Highway,
North Sydney, NSW, 2060, Australia
Tel: (02) 9299 7200
Principal place of business
Suite 302, 93-95 Pacific Highway,
North Sydney, NSW, 2060, Australia
Tel: (02) 9299 7200
55
Bounty Oil & Gas NL
DIRECTORS’ DECLARATION
Annual Report – 2019
a) The directors of Bounty Oil and Gas NL (“the Company”) declare that the financial statements and notes, as set out on pages
16 to 42 are in accordance with the Corporations Act 2001:
(i) comply with Accounting Standards and the Corporations Regulations 2001; and
(ii) give a true and fair view of the financial position as at 30th June 2019 and of the performance for the year ended on that
date of the Company;
b) The Chief Executive Officer and the Chief Financial Officer have each declared that:
(i) The financial records of the company for the financial year have been properly maintained in accordance with Section 286 of
the Corporations Act 2001.
(ii) The financial statements and notes for the financial year comply in all material respects with the Accounting Standards;
(iii) The financial statements and notes give a true and fair view.
c) In the directors’ opinion, there are reasonable grounds to believe that the company will be able to pay its debts as when they
become due and payable.
This declaration is made in accordance with a resolution of the Board of Directors.
Graham Reveleigh
Director
Dated: 30 September 2019
56
Bounty Oil & Gas NL Annual Report – 2019
1. Additional Information Required by ASX Listing Rules
The following is additional information provided in accordance with the Listing Rules of the Australian
Securities Exchange Limited.
Analysis of equity security holders as at 27 September 2019:
a) Analysis of numbers of holders of fully paid ordinary shares:
No. of Securities
1 – 1,000
1,001 – 5,000
5,001 – 10,000
10,001 – 100,000
100,001 and above
No. of
Shareholders
211
120
418
1,607
975
3,331
b)
Twenty largest holders of quoted equity securities at 27 September 2019:
Ordinary Shareholders
Comadvance Pty Ltd.
Robert A Hutchfield
Red Kite Capital Inc.
David Alan McSeveny
G E Reveleigh
Bang Vi Khanh
Tri-Ex Holdings Pty Ltd.
WH Ave LLC
Kestrel Petroleum Pty Ltd.
Granborough Pty Ltd.
Barry Sheedy & Associates Pty
Ltd.
Level 1 PL
Simon Saliba
Colin M & K S Roche
Jordan Vujic
Ann Spooner
PKS & Paul SY Cheung
William John & S Tyler
GH Services Pty Ltd
Robert Cameron Galbraith
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
Fully paid
number
49,248,155
38,148,909
27,022,000
25,663,006
23,377,928
21,880,000
19,177,778
18,000,000
15,175,000
15,000,000
13,893,700
11,284,254
11,000,000
13,900,000
10,578,750
7,772,217
7,050,000
7,000,000
6,783,061
6,500,000
%
5.17%
4.00%
2.83%
2.69%
2.45%
2.29%
2.01%
1.89%
1.59%
1.57%
1.46%
1.18%
1.15%
1.46%
1.11%
0.82%
0.74%
0.73%
0.71%
0.68%
Total Top 20 Holders
348,454,758
36.55%
c) Options as at 27 September 2019:
i)
there were no listed and quoted options over ordinary
shares.
ii)
there were no unlisted options over ordinary shares
60
Bounty Oil & Gas NL Annual Report – 2019
2.
Substantial Shareholders
As at 27 September 2019 there were no substantial shareholders as disclosed in substantial
shareholders notices given to the company.
3.
Issued Shares and Distribution
a) The total number of fully paid ordinary shares on issue on 27 September 2019 was 953,400,982.
b) There were 2,204 holders of less than a marketable parcel of ordinary shares, totalling 57,625,277
shares.
c) The percentage of the total holding of the 20 largest shareholders of ordinary shares was 36.55% of
issued capital.
4.
Stock Exchange Listing
Quotation has been granted for all the ordinary shares of the company on the Australian Securities
Exchange (ASX) under the code BUY.
5.
Income Tax
The company is taxed as a public company.
6. Voting Rights
The voting rights attaching to ordinary shares are governed by the Constitution. At a meeting of
members every person present who is a member or representative of a member shall on a show of
hands have one vote and on a poll, every member present in person or by proxy or by attorney or duly
authorised representative shall have one vote for each share held. No options have any voting rights.
7. Additional Information
Information in these financial statements (or in the annual report) that relates to or refers to
petroleum exploration and prospectivity or petroleum or hydrocarbon reserves or resources is based
on information compiled and/or written by Mr Philip F Kelso the CEO of Bounty Oil & Gas NL. Mr Kelso
is a Bachelor of Science (Geology) and has practised geology and petroleum geology for in excess of 45
years. He is a member of the Petroleum Exploration Society of Australia and a Member of the
Australasian Institute of Mining and Metallurgy. Mr Kelso is a qualified person as defined in the ASX
Listing Rules: Chapter 19 and consents to the reporting of that information in the form and context in
which it appears in this report.
The company continues to comply with the ASX Listing Rules disclosure requirements. The company
reports to ASX which makes available all reports to those who wish to access them. All ASX releases
and other background information are posted regularly on the company’s website. The company
intends to post on its website its annual report and all other required notices to its shareholders.
The board reviews and receives advice on areas of operational and financial risks. Business risk
management strategies are developed as appropriate to mitigate all identified risks of the business.
The directors are aware of the guidelines for the content of a code of conduct to guide compliance
with legal and other obligations to shareholders but have not formally established such a code. Where
applicable to its activities, the directors ensure that the company is responsible to its shareholders,
employees, contractors, advisers, individuals and the community.
8.
Secretary
The name of the Secretary of the company is Mr. Sachin Saraf.
9.
Share Buy Back
There is no current on market share buy back.
61
Bounty Oil & Gas NL Annual Report – 2019
Schedule of Petroleum Tenements – 27 September 2019
Australia - Queensland
Cooper Eromanga Basin
Permit
ATP 1189P (formerly 259P)
Naccowlah Block
PL 23
PL 24
PL 25
PL 26
PL 35
PL 36
PL 62
PL 76
PL 77
PL 78
PL 79
PL 82
PL 87
PL 105/PL 287
PL 496 (ex PL 107)
PL 495 (ex PL 109)
PL 133
PL 149
PL 175
PL 181
PL 182
PL 1026 formerly PL 189
PL 302
PL 1047
PCA 247
Basin
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
SW Qld – Cooper -
Eromanga Basin.
62
Interest
Gross km2 Net km2 Operator
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
2%
1,064.5
21.3
Santos 2
234.6
200.9
256
255.9
136.5
60.9
64.7
39.5
12.2
12.1
6.5
10.4
27.5
12.2
12.2
9.2
12.2
12.2
27.5
18.3
27.5
18.3
12.2
30.6
127.8
4.7
4.0
5.1
5.1
2.7
1.2
1.3
0.8
0.2
0.2
0.1
0.2
0.6
0.2
0.2
0.2
0.2
0.2
0.6
0.4
0.6
0.4
0.2
0.6
2.6
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Santos 2
Bounty Oil & Gas NL Annual Report – 2019
Surat Basin
PL 2 Alton Oilfield
PL 2A
PL 2B
PL 2C
PL 441 (ex PL 119)
PCA 159 ex ATP 1190
Spring Grove (SG) 5)
ATP 2028
PPL 58 Pipeline Licence6
Qld - Surat Basin
Qld - Surat Basin
Qld - Surat Basin
Qld - Surat Basin
Qld - Surat Basin
100%
81.75%
81.75%
100%
100%
Qld - Surat Basin
24.748%
Qld - Surat Basin
Qld – Surat Basin
50%
100%
16
66.8
136.7
45.2
21.4
13.2
16
54.6
111.7
45.2
21.4
Bounty1
Bounty1
Bounty1
Bounty1
Ausam7
3.3
AGL4
554.4
277.2
Ausam7
Ausam7
Table 2 Schedule of other Australian Petroleum Permits and Tenements – 27 September 2019
Permit
Australia – South Australia
PRL 35 37 38 41 43-45 48
49 – FO inclusive replacing
EL 218 (Post Permian)
Australia – Western Australia
PL 104 - L16 (Petroleum
Lease)
Australia – Offshore
AC/P32
PEP 11
Basin
Interest
Gross km2 Net km2
Operator
SA – Cooper - Eromanga
Basin.
23.28%
1,603.5
373.3
WA - Carnarvon Basin
onshore
100%
79.5
79.5
Beach
Energy
Ltd9
Rough
Range 3
Ashmore Cartier
Territory - Vulcan
Basin
100%
336
336
Bounty1
NSW - Sydney Basin
15%
4,577
686.5
Asset
Energy8
Operators / Notes
1. Bounty Oil & Gas NL
2. Santos Limited group companies
3. Rough Range Oil Pty Ltd. - is a wholly owned subsidiary of Bounty Oil & Gas NL
4. AGL Gas Storage PL
5. PCA (SG) – Potential Commercial Area Spring Grove joint venture block
6. Pipeline Licence 58
7. Ausam Resources Pty Ltd - is a wholly owned subsidiary of Bounty Oil & Gas NL
8. Asset Energy Pty Ltd is a wholly owned subsidiary of Advent Energy Ltd
9. Beach Energy Limited
63
Bounty Oil & Gas NL Annual Report – 2019
ABBREVIATIONS
The following definitions are provided for readers who are unfamiliar with industry terminology:
AVO
Barrel (bbl/BBL)
Specialised analysis of seismic data comparing amplitude of sound waves versus
collection point offsets
A unit of volume of oil production, one barrel equals 42 US gallons, 35 imperial gallons
or approximately 159 litres
Basin
BCF/Bcf
A segment of the earth’s crust which has down warped and in which sediments have
accumulated, such areas may contain hydrocarbons.
Billion cubic feet, i.e. 1,000 million cubic feet (equivalent to approximately 28.3 million
cubic metres) of gas.
BOPD/BPD
Barrels of oil per day; barrels per day.
Contingent Resources
Discovered resources, not yet fully commercial
CSG
GIIP
Lead
License
Coal seam gas.
Gas initially in place
A structural or stratigraphic feature which has the potential to contain hydrocarbons
An agreement in which a national or state government gives an oil Company the rights
to explore for and produce oil and/or gas in a designated area.
MCF/Mcf
Thousand cubic feet – the standard measure for natural gas.
MDRT
Measured depth below Rotary Table
MMB/mmb,
MMBO/mmbo
MMCF/mmcf,
MMCFG/mmcfg,
MMCFGPD/mmcfgpd
P10
P90
PCA
Million barrels, million barrels of oil.
Million cubic feet, million cubic feet of gas, million cubic feet of gas per day
10% probability of occurrence
90% probability of occurrence
Potential Commercial Area (State of Queensland)
Permeability
The degree to which fluids such as oil, gas and water can move through the pore spaces
of a reservoir rock.
Permit
Play
A petroleum tenement, lease, licence or block.
A geological concept which, if proved correct, could result in the discovery of
hydrocarbons.
Plug and Abandon
(P&A)
The process of terminating operations in a well. Cement plugs are set in the borehole
and the rig moves off the location. The borehole is thus left in a safe condition. In some
cases, where the Operator considers it possible that the well may be re-entered at a
later date, the well may be only temporarily plugged and abandoned.
64
Bounty Oil & Gas NL Annual Report – 2019
Pmean
Porosity
The average (mean) probability of occurrence
The void space in a rock created by cavities between the constituent mineral grains.
Liquids are contained in the void space.
Prospect (petroleum)
A geological or geophysical anomaly that has been surveyed and defined, usually by
seismic data, to the degree that its configuration is fairly well established and on which
further exploration such as drilling can be recommended.
Prospective Resources
Undisclosed resources
PSA
PSC
PRL
Reserves
Reservoir
Production Sharing Agreement
Production Sharing Contract
Petroleum Retention Lease (South Australia)
Quantities of economically recoverable hydrocarbons estimated to be present within a
trap, classified as prove, probably or possible.
A subsurface volume of rock of sufficient porosity and permeability to permit the
accumulation of crude oil and natural gas under adequate trap conditions.
Seal, Sealing Formation
A geological formation that does not permit the passage of fluids. Refer also to Cap
Rock.
Seismic Survey
A type of geophysical survey where the travel times of artificially created seismic waves
are measured as they are reflected in a near vertical sense back to the surface from
subsurface boundaries. This data is typically used to determine the depths to the tops
of stratigraphic units and in making subsurface structural contour maps and ultimately
in delineating prospective structures.
Spud
To start the actual drilling of a well.
Stratigraphic Trap
A type of petroleum trap which results from variations in the lithology of the reservoir
rock, which cause a termination of the reservoir, usually on the up dip extension.
Structure
A discrete area of deformed sedimentary rocks, in which the resultant bed configuration
is such as to form a potential trap for migrating hydrocarbons.
Sub-basin
A localised depression within a basin.
TCF/Tcf
TVDS
Up-dip
Trillion cubic feet.
Total vertical depth below Sea Level
At a structurally higher elevation within dipping strata.
65
Bounty Oil & Gas NL Annual Report – 2019
CORPORATE DIRECTORY
Board of Directors
Share Registry
Graham C Reveleigh (Chairman)
Charles Ross
Roy Payne
Security Transfer Registrars Pty Ltd
770 Canning Highway
Applecross, WA, 6153
Chief Executive Officer
Philip F. Kelso
Company Secretary
Sachin Saraf
Telephone:
Facsimile:
Email: registrar@securitytransfer.com.au
+61 3 9628 2200
+61 8 9315 2233
Bankers
BankWest, Sydney
Commonwealth Bank of Australia, Sydney
Registered and Principal Office
Legal Counsel
Suite 302, 93 – 95 Pacific Highway
North Sydney NSW 2060
Australia
Dentons Australia
77 Castlereagh Street
Sydney, NSW, 2000
Telephone: +61 2 9299 2007
+61 2 9299 7300
Facsimile:
corporate@bountyoil.com
Email:
www.bountyoil.com
Website:
Independent Consulting Petroleum Engineers
Apex Energy Consultants Inc,
700, 815 8th Avenue S.W.
Calgary, Alberta, T2P 3P2
Canada
Auditors
Mr. William M Moyes
Moyes Yong & Co
Suite 1301, Level 13
115 Pitt Street
Sydney NSW 2000
Telephone: +61 2 8256 1100
Facsimile: +61 2 8256 1111
66