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Jadestone Energy PLC 2022 Half Year Results and Interim Dividend

20/09/2022 7:00am

UK Regulatory (RNS & others)


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Jadestone Energy PLC

20 September 2022

Jadestone Energy

2022 Half Year Results and Interim Dividend Declaration

20 September 2022-Singapore: Jadestone Energy plc (AIM:JSE) ("Jadestone" or the "Company"), an independent oil and gas production company and its subsidiaries (the "Group"), focused on the Asia Pacific region, reports today its unaudited condensed consolidated interim financial statements, as at and for the six-month period ended 30 June 2022 (the "financial statements").

Management will host a conference call today at 9:00 a.m. UK time, details of which can be found in the release below.

Paul Blakeley, President and CEO commented:

"Jadestone delivered record financial results in the first half of 2022, with production increasing by c.50% compared to the first half of 2021, driven by a full period contribution from the Malaysian assets acquired in August 2021 and the impact of the Montara drilling programme in the second half of 2021, albeit offset by an unplanned shutdown at Montara early in 2022 due to a compressor engine failure. Revenues and adjusted EBITDAX increased by 63% and 113% respectively, due to the increase in production volumes and higher realised oil prices. As a result, we ended the period with a net cash balance of US$161.6 million, an increase of almost 40% compared to year-end 2021. Jadestone remains debt free.

Despite all this, recent operational performance at Montara has been disappointing, especially given the substantial upgrade and repair work done to date. As previously announced, the field is currently shut-in as we progress a remediation plan for the Montara Venture FPSO following defects identified earlier this year. The plan involves emptying, cleaning, inspecting and, where necessary, resolving any defects in the tanks and hull of the FPSO. In particular, we are moving ahead with the permanent repair of 2C crude oil cargo tank and 4S ballast tank whilst prioritising entry and activity in other tanks in preparation for operational readiness. As we focus on safety and integrity, this activity will continue until we can ensure a safe and reliable restart of the FPSO. In parallel, we are making good progress in the appointment of, and work scope for, the independent reviewer, who will work with us to provide final assurance to Jadestone and the regulator on our remediation plans and operational readiness prior to the restart of production operations. While we understand that the lack of a firm restart date is frustrating for many of our stakeholders, our focus is on the remediation plan and its successful execution which, in turn, will restore confidence in the significant remaining value we see at Montara.

We have also initiated a fundamental review of our hull and tank inspection and repair regime, which will include our maintenance approach, operating systems and organisational structure. As a near-term action to assist management, Jadestone's Board of Directors has established a special subcommittee, which will work closely with Company's executive and senior operations leadership, providing both additional support and challenge, while the Montara FPSO hull and tank remediation work is in progress. This will include weekly progress updates and reports.

The balance sheet strength we have built in recent years, and the confidence in our existing asset portfolio and its planned growth, means we are well-positioned to weather the Montara shut-in without any anticipated impact on our investment programmes, inorganic growth, or near-term shareholder returns. We expect capital expenditures for the year to be in line with guidance of US$90.0 - 105.0 million. We have also taken the decision to increase the interim dividend by 10% to US$3.0 million and, subject to market conditions, we intend to complete the US$25.0 million share buyback programme launched in August and which has so far returned an incremental US$4.9 million to shareholders. The next phase of the shareholder returns strategy announced in June will be determined by the timing of production restart at Montara, our portfolio's operational performance, realised oil prices, and the timing and scale of incremental inorganic growth opportunities.

The Company continues to deliver on its growth strategy. In June, we took a final investment decision on the Akatara gas development on the Lemang PSC in Indonesia, with activity at the site now well underway. Separately, the acquisition of the outstanding 10% stake in the Lemang PSC is expected to complete soon. In July, we announced the acquisition of a non-operated interest in the producing Northwest Shelf ("NWS") oil project offshore Australia, and are making good progress towards closing this transaction in Q4 2022.

Our strong balance sheet underlines the success of our business model, supporting our planned investments for growth, and while the recent Montara asset incident is unfortunate, we are determined to fix it and deliver the original value proposition vindicating our strategy in the Asia Pacific region."

Paul Blakeley

EXECUTIVE DIRECTOR,

PRESIDENT AND CHIEF EXECUTIVE OFFICER

2022 FIRST HALF RESULTS SUMMARY

 
 USD'000 except where indicated          H1 2022   H1 2021    FY 2021 
--------------------------------------  --------  --------  --------- 
 
 Production, boe/day                      15,008     9,934     12,545 
 Realised oil price per barrel of 
  oil equivalent (US$/boe)(1)             109.52     67.70      74.34 
 Realised gas price per million 
  standard cubic feet 
  (US$/mmscf)                               2.03         -       1.61 
 Revenue                                 225,639   138,158    340,194 
 Operating costs per barrel of oil 
  equivalent (US$/boe)(2)                  25.71     28.16      26.22 
 Adjusted EBITDAX(2)                     138,608    65,179    157,948 
 Profit/(Loss) after tax                  49,486     2,495   (13,742) 
 Earnings/(Loss) per ordinary share: 
  basic (US$)                               0.11      0.01     (0.03) 
 Earnings/(Loss) per ordinary share: 
  diluted (US$)                             0.10      0.01     (0.03) 
 Dividend per ordinary share (US 
  )(3)                                      0.65      0.59       1.93 
 Operating cash flows before movement 
  in working capital                     126,481    54,376     96,622 
 Capital expenditure                      13,621    16,221     55,996 
 Net cash(2)                             161,628    48,291    117,865 
 

Operational and financial summary

l Production increased 51% during H1 2022 to 15,008 bbls/d (H1 2021: 9,934 bbl/d). Production benefitted from a full period of the PenMal Assets acquired in August 2021 and the Montara activity programme in H2 2021, offset by unscheduled downtime at Montara early in 2022, a planned maintenance shutdown at Stag in May, and the shut-in of the non-operated PenMal Assets in February 2022 due to FPSO class suspension;

l Average realised oil price(1) in H1 2022 was US$109.52/bbl, 62% higher than H1 2021. The realised price includes a weighted average premium across the assets of US$6.99/bbl (H1 2021: US$3.12/bbl);

l Revenue of US$225.6 million in H1 2022, up 63% from H1 2021 at US$138.2 million, due to higher production and higher average realised prices;

l Closing crude stocks as at 30 June 2022 totalled 417,216 bbls, which were subsequently sold in the second half of 2022, generating provisional receipts of US$45.3 million, from a provisional weighted average realised price of US$108.97/bbl;

l As at 30 June 2022, there was an underlift production entitlement carried forward of 130,359 bbls at the PenMal Assets, resulting in a receivable of US$16.8 million, calculated based on the average June 2022 Dated Brent price plus latest realised premium;

l Unit operating costs(4) of US$25.71/boe, down 9% from US$28.16/bbl in H1 2021 due to inclusion of the PenMal Assets, which have a lower opex/boe compared to the Australian producing assets;

l Adjusted EBITDAX improved 113% to US$138.6 million compared to US$65.2 million in H1 2021, predominately due to increased production, higher oil prices and lower one-off project expenditures in Other Expenses;

l Net profit after tax in H1 2022 of US$49.5 million compared to US$2.5 million in H1 2021;

l Operating cash flows before movements in working capital in H1 2022 of US$126.5 million, up 133% compared to H1 2021 ;

l Capital expenditure in H1 2022 of US$13.6 million, down 16% compared to H1 2021 due to the phasing of expenditure in H2 2022;

l Cash balances of US$161.6 million as at 30 June 2022 (H1 2021: US$48.3 million), with no debt outstanding; and

l Recommended interim dividend for FY2022 of USc0.65/share(3) (H1 2021: USc0.59/share), equivalent to a total distribution of US$3.0 million (H1 2021: US$2.8 million). On 2 August 2022, the Company announced the launch of a share buyback programme with a maximum amount of US$25.0 million. As at 16 September 2022, 4.7 million of shares had been acquired at an accumulated cost of US$4.9 million.

Business development

l On 16 November 2019, the Group executed a sale and purchase agreement with OMV New Zealand Limited ("OMV"), to acquire an operated 69% interest in the Maari project, subject to customary conditions, including government approvals. Following legislative changes to New Zealand's upstream regulatory framework at the end of 2021, Jadestone has continually engaged with OMV and the New Zealand Government to seek clarity on the processes, terms and associated timeline required to complete the Maari transaction. Despite these efforts, it remains unclear under what circumstances and in what timeframe completion of the transaction and transfer of operatorship can occur;

l On 6 June 2022, the Group announced that a final investment decision had been taken on the Akatara gas field development onshore Indonesia, following the receipt of necessary consent from the Indonesian upstream regulator. The project is now in the development phase with first gas anticipated in the first half of 2024;

l On 24 November 2021, the Group executed a settlement and transfer agreement with PT Hexindo Gemilang Jaya to acquire the remaining 10% interest in the Lemang PSC for US$0.5 million and a waiver of unpaid amounts related to the PSC. Indonesian government approval is anticipated in Q4 2022; and

l On 28 July 2022, the Group announced the execution of a sale and purchase agreement with BP Developments Australia Pty Ltd ("BP") to acquire BP's non-operated 16.67% working interest in the Cossack, Wanaea, Lambert and Hermes oil fields development offshore Western Australia, for a total initial headline cash consideration of US$20.0 million, and certain subsequent contingent and decommissioning security payments.

Significant events

l On 7 February 2022, the Bunga Kertas FPSO, deployed at the non-operated PenMal Assets, had its class suspended, resulting in the non-operated PenMal Assets being shut-in and production suspended. Production is expected to remain shut-in for the remainder of 2022. The estimated adjustment to the production guidance provided in August 2022 to arrive at the current production guidance for full year 2022 is a reduction of c.720 boe/d;

l As previously announced, on 17 June 2022, between three to five cubic metres of crude oil was released to sea during a routine oil transfer between tanks on the Montara Venture FPSO. The facility was immediately shut-in as a precaution and the relevant authorities notified. Following a temporary repair and isolation of the 2C cargo tank where the leak originated, production was restarted on 4 July 2022 while a permanent repair was being developed;

l On 12 August 2022, an additional defect was identified in a ballast water tank on the Montara Venture FPSO during preparation work for a permanent repair to the 2C cargo tank. The Group took the decision to temporarily shut-in production at Montara to prioritise the permanent repairs, removing a number of production operations personnel in order to provide accommodation for additional inspection and repair crews due to an inability to simultaneously accommodate both; and

l On 15 September 2022, Jadestone's Board of Directors established a temporary special sub-committee to assist management during the ongoing Montara FPSO hull and tank workstreams. It will receive weekly progress reports on the Montara FPSO remediation activities, and interact directly with the Group's senior operations leadership to review actions and progress towards the remediation plan's objectives, including the restart of production.

2022 Guidance

l Production: 11,000 - 13,000 boe/d (as announced on 12 September 2022, the production forecast was decreased due to the shut-in of production from the Montara fields);

l Unit opex: US$ 31.00 - 37.00/boe (increased from previous guidance at US$23.00 - US$28.00 primarily due to incorporating the lower production forecast above) ; and

l Capex: US$90.0 - 105.0 million (unchanged).

(1) Realised oil price represents the actual selling price inclusive of premiums.

(2) Operating costs per boe, adjusted EBITDAX and net cash are non-IFRS measures and are explained in further detail below.

(3) Dividend per ordinary share calculated based on outstanding number of shares at period/year end. The actual dividend per share will reflect any changes in the shares outstanding between the period/year end and the associated record date including the shares buyback.

(4) Unit operating costs per boe before workovers and movement in inventories but including net lease payments and certain other adjustments (see non-IFRS measures below).

Enquiries

 
 Jadestone Energy plc. 
 Paul Blakeley, President and CEO           +65 6324 0359 (Singapore) 
 Bert-Jaap Dijkstra, CFO 
 Phil Corbett, Investor Relations Manager   + 44 7713 687 467 (UK) 
                                            ir@jadestone-energy.com 
 
 Stifel Nicolaus Europe Limited (Nomad,     +44 (0) 20 7710 7600 
  Joint Broker)                              (UK) 
 Callum Stewart / Jason Grossman / Ashton 
  Clanfield 
 
 Jefferies International Limited (Joint     +44 (0) 20 7029 8000 
  Broker)                                    (UK) 
 Tony White / Will Soutar 
 
 Camarco (Public Relations Advisor)         +44 (0) 203 757 4980 
                                             (UK) 
 Billy Clegg / Georgia Edmonds / James      jadestone@camarco.co.uk 
  Crothers 
 

Conference call and webcast

The management team will host an investor and analyst conference call at 9:00 a.m. (London)/4:00 p.m. (Singapore) today, Tuesday, 20 September 2022, including a question-and-answer session.

The live webcast of the presentation will be available at the below webcast link. Dial-in details are provided below. Please register approximately 15 minutes prior to the start of the call.

The results for the financial period ended 30 June 2022 will be available on the Company's website at: www.jadestone-energy.com/investor-relations/

Webcast link: https://app.webinar.net/VXGleQG4RWA

Event title: Jadestone Energy plc first-half 2022 results

Time: 9:00 a.m. (UK time) / 4:00 p.m. (Singapore time)

Date: Tuesday, 20 September 2022

Conference ID: 65496332

Dial-in number details:

 
  Country                     Dial-In Numbers 
  United Kingdom                  08006522435 
                              --------------- 
  Australia                        1800076068 
                              --------------- 
  Canada (Toll free)             888-390-0546 
                              --------------- 
  France                           0800916834 
                              --------------- 
  Germany                         08007240293 
                              --------------- 
  Hong Kong                         800962712 
                              --------------- 
  Indonesia                     0078030208221 
                              --------------- 
  Japan                          006633812569 
                              --------------- 
  Malaysia                         1800817426 
                              --------------- 
  Netherlands                     08000227908 
                              --------------- 
  New Zealand                      0800453421 
                              --------------- 
  Singapore                        8001013217 
                              --------------- 
  Spain                             900834776 
                              --------------- 
  Sweden                           0200899189 
                              --------------- 
  Switzerland                      0800312635 
                              --------------- 
  United States (Toll free)      888-390-0546 
                              --------------- 
 

DIVID DECLARATION AND PROGRESS SHARE BUYBACK PROGRAMME

On 20 September 2022, the Directors declared a 2022 interim dividend of 0.65 US cents /share, equivalent to a total distribution of US$ 3.0 million. The timetable for the dividend payment is as follows:

l Ex-dividend date: 29 September 2022

l Record date: 30 September 2022

l Payment date: 14 October 2022

The Group's growth-orientated strategy remains unchanged, with the objective of establishing a leading Asia-Pacific upstream company through acquiring and maximising the value of producing fields and development assets. The Group prioritises organic reinvestment, and maintains a conservative capital structure in order to capitalise on inorganic growth opportunities as they arise. Notwithstanding this, the Group believes that its production and development led business model is fundamentally pre-disposed to provide meaningful shareholder returns, particularly during times of higher oil prices. The Company targets a sustainable base dividend, with a targeted split one-third to an interim dividend and two-thirds to a final dividend, growing over time in line with underlying cash flow generation. The base dividend may be augmented over time by additional shareholder returns (in the form of share buybacks, special dividends and/or tender offers) if deemed appropriate by the Company.

The Company does not offer a dividend reinvestment plan and does not offer dividends in the form of ordinary shares.

On 2 August 2022, the Company announced the launch of a share buyback programme (the "Programme") in accordance with the authority granted by the shareholders at the Company's annual general meeting on 30 June 2022. The maximum amount of the Programme is US$25.0 million, and the Programme will not exceed 46,574,528 ordinary shares. There is no certainty on the volume of shares that may be acquired, nor any certainty on the pace and quantum of acquisitions.

As at 16 September 2022, the Company had acquired 4.7 million shares at a weighted average cost of GBP 0. 89 per share, resulting in an accumulated total of US$4.9 million.

ENVIRONMENT, SOCIAL AND GOVERNANCE ("ESG")

As a responsible upstream operator, Jadestone contributes to an orderly energy transition by helping to meet regional Asia-Pacific energy demand whilst minimising the environmental footprint of its operations. In doing so, Jadestone aims to bring positive social and economic benefits for its stakeholders, local communities and people associated with its operations.

Jadestone published its third Sustainability Report in June 2022, which covered the Group's ESG performance in 2021, as well as commitments to further improvements in 2022 across key focus areas. This section provides an overview of period-to-date performance of the Group, representing the Stag and Montara fields, the PenMal operated assets and, where relevant, the Akatara gas development.

Net Zero and GHG emissions

The Group committed in June 2022 to achieve Net Zero Scope 1 and 2 GHG emissions from its operated assets by no later than 2040. The detail of this commitment as well as Jadestone's strategy through the energy transition can be viewed on Jadestone's website(1) .

A key element of the Net Zero commitment is the development of an emissions reduction roadmap for Jadestone's operated assets, which will inform the interim GHG reduction targets for the Group. Jadestone has engaged a reputable international consultant to support its Net Zero workstreams, which will be progressed throughout H2 2022 and into 2023. The Group is on track to publish its Net Zero roadmap in 2023 and is committed to being transparent in the implementation of the roadmap on at least an annual basis.

Illustrative of its efforts to minimise GHG emissions, a solar photovoltaic installation was piloted at the Akatara gas field development in Indonesia in April 2022, replacing diesel generators at four well pads. Solar power now fully meets well pad lighting and electricity needs, with potentially broader application within the Akatara development, such as use in the accommodation camp. In collaboration with other operators in the area, Jadestone is participating in the planting of over 27,000 mangrove trees to positively impact the health and wellness of local communities and environment.

HSE performance

The Group's priority remains the health and safety of its staff and contractors, along with ensuring that any negative environmental impacts from operations are minimised.

At the operated PenMal Assets, there have been no recordable incidents since Jadestone assumed operatorship in August 2021. Similarly, since construction started at the Akatara gas development in Indonesia earlier this year, no recordable incidents have occurred. In Australia, there were three recordable incidents with one at Stag classified as a Lost Time Injury ("LTI"). The crew member concerned suffered a minor injury, recovered quickly and is back to work. The LTI was managed in accordance with Jadestone's Injury & Illness Management Procedure, with a detailed investigation completed and ensuing actions and engineering modifications fully implemented.

(1) https://www.jadestone-energy.com/jadestone-announces-2040-net-zero-target/

As referenced previously, in June 2022, between three to five cubic metres of crude oil was released to sea during a routine oil transfer between tanks on the Montara Venture FPSO. Production operations resumed on 4 July 2022 but were then shut-in again in August 2022 after an additional internal defect was identified in a ballast water tank on the FPSO. The Group took the decision to temporarily shut-in production at Montara to prioritise permanent repairs, removing a number of production operations personnel in order to provide accommodation for additional inspection and repair crews due to an inability to simultaneously accommodate both.

Governance

On 7 April 2022, the Group announced the immediate appointment of Jenifer Thien as an independent non-executive director. Jenifer brings knowledge and experience in environmental, social and governance ("ESG") strategy. Jenifer joined the Remuneration, Governance and Nomination, and Health, Safety, Environment and Climate (HSEC) committees.

On 29 April 2022, Daniel Young stepped down from his role as the Chief Financial Officer ("CFO") and Executive Director and left the Group. Michael Horn took the role of interim CFO until 22 August 2022, when Bert-Jaap Dijkstra was appointed by the Board as CFO and Executive Director.

Jadestone's Board of Directors (the "Board") supports management's decision to shut-in operations at Montara to focus on the inspection, maintenance and repair activities associated with the Montara FPSO hull and tanks , recognising the elevated requirements to restart operations as outlined within the General Direction issued by NOPSEMA on 12 September 2022. The Board has every confidence in the Group's abilities to execute the remediation plan efficiently and effectively and to the satisfaction of the regulatory authorities.

D uring this period, a technical subcommittee of the Board will work more closely with senior management, providing both support and challenge, while the Montara FPSO hull and tank remediation plan is in progress. This will include weekly progress updates and reports.

OPERATIONAL REVIEW

Producing assets

Australia

Montara project

The Montara project, in production licences AC/L7 and AC/L8, is located 254 km offshore Western Australia, in a water depth of approximately 77 metres. The Montara project comprises three separate fields being Montara, Skua and Swift/Swallow, which are produced through an owned FPSO, the Montara Venture.

As at 31 December 2021, the Montara assets had proven plus probable reserves of 20.9mm barrels of oil, 100% net to Jadestone.

The fields produce light sweet crude ( 42(o) API, 0.067% mass sulphur), which typically sells for average Dated Brent plus the average Tapis differential of the prior two months before the lifting date. This premium ranged from US$3.53/bbl to US$6.19/bbl during H1 2022.

Montara production averaged 7,509 bbls/d in H1 2022 (H1 2021: 7,269 bbls/d). The higher production was a result of the drilling of H6 and the subsea workovers of Skua 10 and 11 in the second half of 2021. The additional production was partially offset by an unplanned gas turbine replacement and a temporary loss of subsea communication impacting uptime from the Swallow-11 well during H1 2022.

As previously announced, on 17 June 2022, between three to five cubic metres of crude oil was released to sea during a routine oil transfer between tanks on the Montara Venture FPSO. The facility was immediately shut-in as a precaution and the relevant authorities notified. Following a temporary repair and isolation of the 2C cargo tank where the leak originated, production was restarted on 4 July 2022 while a permanent repair was being developed.

On 12 August 2022, an additional internal defect was identified in a ballast water tank on the Montara Venture FPSO during preparation work for a permanent repair to the 2C cargo tank. The Group took the decision to temporarily shut-in production at Montara to prioritise permanent repairs, removing a number of production operations personnel in order to provide accommodation for additional inspection and repair crews due to an inability to simultaneously accommodate both.

There were three liftings during H1 2022, resulting in total sales of 1.3 mmbbls, compared to 1.5 mmbbls during H1 2021 from the same number of liftings.

Stag oilfield

The Stag oilfield, in production licence WA-15-L, is located 60 km offshore Western Australia in a water depth of approximately 47 metres.

As at 31 December 2021, the field contained total proved plus probable reserves of 12.6mm barrels of oil, 100% net to Jadestone.

The Stag oilfield produces heavier sweet crude ( 18(o) API, 0.14% mass sulphur), which historically sells at a premium to Dated Brent. The premium of the H1 2022 lifting was US$23.72/bbl compared to a weighted average of US$11.09/bbl in H1 2021, reflecting the increase in refinery demand for heavy oil with low sulphur content.

Production during H1 2022 was 2,057 bbls/d, compared to 2,665 bbls/d during H1 2021, due to a scheduled maintenance shutdown in May 2022. The shutdown was to perform pressure vessel inspections and occurs once in every three years.

Due to the lifting schedules, there was one lifting in H1 2022 for 0.3 mmbls compared to two in H1 2021 for 0.5mmbls.

Malaysia

Operated: PM 323 and PM 329 PSCs & Non-operated: PM 318 and AAKBNLP PSCs

The PenMal Assets consist of four licences, two of which are operated by the Group. The two operated licences comprise a 70% interest in the PM329 PSC, containing the East Piatu field, and a 60% interest in the PM323 PSC, which contains the East Belumut, West Belumut and Chermingat fields. Both PSCs are located approximately 230km northeast of Terengganu in shallow water.

The two non-operated ("OBO") licences consist of 50% working interests in each of the PM318 PSC and in the Abu, Abu Kecil, Bubu, North Lukut, and Penara oilfields (the "AAKBNLP") PSC. The two non-operated PSCs are located in the same region as PM329 and PM323.

As at 31 December 2021, the PenMal Assets contained total proved plus probable reserves of 11.2mmboe, net to Jadestone.

The PenMal Assets produce light sweet crude that is blended to Tapis grade (43 (o) API, 0.04% mass sulphur). This premium ranged between US$0.96/bbl to US$6.76/bbl in H1 2022.

During H1 2022, the average production from the PenMal Assets was 4,578 bbls/d of oil and 5,191 mscf/d of gas, creating a combined production of 5,443 boe/d , net to Jadestone's working interest. There was no comparable production in H1 2021 as the acquisition of the PenMal Assets was completed in August 2021.

On 7 February 2022, the Bunga Kertas FPSO, deployed at the non-operated assets, had its class suspended, resulting in the fields having to shut-in and cease production. Since the class suspension, there has been no production and it is expected that production will remain shut-in for the remainder of 2022. Currently, following a subsequent safety incident, the operator has paused its FPSO repair plan and is assessing the full range of alternatives, which include a comprehensive programme of repairs, an asset divestment or, given that the OBO licenses expire in 2024, a move towards decommissioning the asset 12 months earlier than originally planned.

There were seven oil liftings during H1 2022, for total sales of 0.5 mmbbls in addition to the sale of 939.7 mmscf of gas.

Pre-production assets

Indonesia

Lemang PSC

The Lemang PSC (Jadestone 90% working interest) is located onshore Sumatra, Indonesia. The PSC contains the Akatara field, which has been substantially de-risked with 11 wells drilled into the structure, plus three years of oil production history, up until the field ceased oil production in December 2019. Jadestone is redeveloping Akatara to supply gas, condensate and LPGs for local and regional use.

The Akatara gas field has been independently estimated to contain a 2C gross resource (pre local government back-in rights) of 63.7 bcf of sales gas, 2.5 mmbbls of condensate and 5.6 mmboe of LPG, equating to a combined 18.7 mmboe of resource, or 16.8 mmboe net to Jadestone's existing 90% working interest.

On 30 June 2021, the Minister of Mines and Energy of Indonesia issued a Ministerial decree that facilitates the development and commercialisation of the Akatara gas field, allocating gas sales from the gas field in the Lemang PSC to a subsidiary of PT Perusahaan Listrik Negara, the national electricity utility, and the associated production and sales of LPG to the local domestic market in Jambi province, together with condensate sales to a local buyer. On 1 December 2021, a gas sale agreement was signed between Jadestone and PT Pelayanan Listrik Nasional Batam, as buyer.

On 24 November 2021, the Group announced the acquisition of the remaining 10% interest in the PSC from PT Hexindo Gemilang Jaya ("Hexindo"), subject to customary approvals. The transaction was approved by the shareholders of Hexindo's ultimate parent company, Eneco Energy Limited, on 20 June 2022 and the government approval, representing the last required approval for closing, is anticipated in Q4 2022.

On 6 June 2022, the Group announced that a final investment decision had been taken on the Akatara field development following the necessary approvals by the Indonesian upstream regulator. The Group awarded the engineering, procurement, construction and installation contract on 3 June 2022 and development activities have commenced. Jadestone is pursuing a low-cost development for the field including efficient use of existing wells and infrastructure thereby minimising the incremental impact on the local environment. The Akatara gas project remains on track for first gas in the first half of 2024.

Vietnam

Block 51 and Block 46/07 PSCs

Jadestone holds a 100% operated working interest in the Block 46/07 and Block 51 PSCs, both in shallow water in the Malay Basin, offshore southwest Vietnam.

The two contiguous blocks hold three discoveries: the Nam Du gas field in Block 46/07 and the U Minh and Tho Chu gas/condensate fields in Block 51, with aggregate 2C resources of 93.9 mmboe.

The Tho Chu discovery in Block 51 is currently under a suspended development area status, with the exploration period expiring in June 2023.

Jadestone has, in recent months, been negotiating with the end-user of gas from its offshore discoveries. These discussions are still at an early stage, but support the prospect of meaningful progress towards commercialising the significant and strategic resource in Jadestone's licences. Development of this resource would lessen Vietnam's future dependence on expensive imports of natural gas and contribute towards the country's stated goal of net zero greenhouse gas emission by 2050.

Pending acquisition

Australia

North West Shelf Project

On 28 July 2022, the Group executed a sale and purchase agreement with BP Developments Australia Pty Ltd to acquire BP's non-operated 16.67% working interest in the Cossack, Wanaea, Lambert and Hermes oil field development (the "North West Shelf Project"), offshore Australia for a total initial headline cash consideration of US$20.0 million, and certain subsequent contingent and decommissioning payments.

The economic effective date of the acquisition is 1 January 2020, meaning that the Group will receive all economic benefits since that date. The Group estimates that the final closing adjustment will be higher than the initial cash consideration of US$20.0 million, in effect representing a net cash income to Jadestone. Upon closing, the Group will pay US$41 million in cash, representing the first of three instalments to be made relating to the decommissioning trust fund payment.

The two final instalments of the decommissioning trust fund payment will be completed through two equal cash contributions of US$20.5 million which are payable around or before 31 December 2022 and 2023, respectively.

The completion of the acquisition is subject to customary closing conditions, including various regulatory approvals. The Group anticipates completion of the transaction in Q4 2022.

New Zealand

Maari project

On 16 November 2019, the Group executed a sale and purchase agreement with OMV New Zealand Limited ("OMV"), to acquire an operated 69% interest in the Maari project, located 120 km offshore New Zealand, subject to customary closing adjustments. The transaction has achieved several key milestones with regard to regulatory approvals.

Following legislative changes to New Zealand's upstream regulatory framework at the end of 2021, Jadestone has continually engaged with OMV and the New Zealand Government to seek clarity on the processes, terms and associated timeline required to complete the Maari transaction. Despite these efforts, it remains unclear under what circumstances and in what timeframe completion of the transaction and transfer of operatorship can occur.

FINANCIAL REVIEW

The following table provides selected financial information of the Group, which was derived from, and should be read in conjunction with, the unaudited condensed consolidated interim financial statements for the period ended 30 June 2022.

 
                                                                            Twelve 
                                            Six months   Six months         months 
                                                 ended        ended          ended 
                                               30 June      30 June    31 December 
 USD'000 except where indicated                   2022         2021           2021 
-----------------------------------------  -----------  -----------  ------------- 
 
 Sales volume, barrels of oil equivalent 
  (boe)                                      2,199,583    2,040,792      4,664,297 
 Production, boe/d                              15,008        9,934         12,545 
 Realised oil price per barrel of 
  oil equivalent, US$/boe(1)                    109.52        67.70          74.34 
 Realised gas price per million 
  standard cubic feet, 
  US$/mmscf                                       2.03            -           1.61 
 Revenue                                       225,639      138,158        340,194 
 Production costs                             (83,401)     (62,492)      (206,523) 
 Operating costs per barrel of oil 
  equivalent (US$/boe)(2)                        25.71        28.16          26.22 
 Adjusted EBITDAX(2)                           138,608       65,179        157,948 
 Unit depletion, depreciation & 
  amortisation (US$/boe)                         12.06        15.70          13.67 
 Profit before tax                              87,253       11,148          1,080 
 Profit /(Loss) after tax                       49,486        2,495       (13,742) 
 Earnings/(Loss) per ordinary share: 
  basic (US$)                                     0.11         0.01         (0.03) 
 Earnings/(Loss) per ordinary share: 
  diluted (US$)                                   0.10         0.01         (0.03) 
 Dividend per ordinary share (US 
  )(3)                                            0.65         0.59           1.93 
 Operating cash flows before movement 
  in working capital                           126,481       54,376         96,622 
 Capital expenditure                            13,621       16,221         55,996 
 Net cash(2)                                   161,628       48,291        117,865 
 

Benchmark commodity price and realised price

The actual average realised oil price in H1 2022 increased by 62% to US$109.52/bbl, compared to US$67.70/bbl during H1 2021.

The average benchmark oil price incorporated into the Group's liftings was US$102.53/bbl during H1 2022, an increase of 59% compared to H1 2021 at US$64.58/bbl.

The average premium for the period was US$6.99/bbl, compared to H1 2021 of US$3.12/bbl. The increase reflected the demand for Stag crude which obtained a premium of US$23.72/bbl (H1 2021: US$11.09/bbl) and increases in Tapis linked crude with Montara and the PenMal Assets at US$4.52/bbl (H1 2021: US$1.14/bbl) and US$3.86/bbl (H1 2021: nil), respectively.

(1) Realised oil price represents the actual selling price inclusive of premiums.

(2) Operating cost per boe, adjusted EBITDAX and net cash are non-IFRS measures and are explained below.

(3) Dividend per ordinary share calculated based on outstanding number of shares at period/year end. The actual dividend per share will reflect any changes in the shares outstanding between the period/year end and the associated record date including the shares buyback.

Production and liftings

The Group generated average production of 15,008 boe/d in H1 2022, compared to 9,934 bbls/d in H1 2021. Production increased due to the acquisition of the PenMal Assets in August 2021, which generated additional production of 5,443 boe/d during H1 2022. Montara increased to 7,509 bbl/d from 7,269 bbl/d in H1 2022 due to the completion of the drilling of H6 and the subsea workovers of Skua 10 and 11 at the end 2021 offset by operational issues in H1 2022, in particular downtime associated with changing out the gas compressor engine on the FPSO. Stag production decreased in H1 2022 to 2,057 bbl/d (H1 2021: 2,665 bbl/d) due to a planned shutdown for vessel inspections and natural field decline.

The Group had 11 liftings during the period (H1 2021: five), resulting in sales of 2.0 mmbbls (H1 2021: 2.0 mmbbls). The PenMal Assets contributed seven oil liftings in H1 2022, representing 0.5 mmbbls. In addition, the PenMal Assets produced and sold 939.7 mmscf (approximately 0.2 mmboe) of natural gas. Lifted volumes were lower than the comparable period last year at Montara and Stag due to the phasing of liftings (four in H1 2022 compared to five in H1 2021).

The Australian closing crude inventories of 417,216 bbls were valued at cost of US$25.9 million, which were subsequently sold in the second half of 2022, generating provisional receipts of US$45.3 million, from a provisional weighted average realised price of US$108.97/bbl.

PenMal Assets were in an underlift carried forward position of 130,359 bbls, reflecting a market value of US$16.8 million, calculated based on the average June 2022 Dated Brent price plus latest realised premium.

Revenue

The Group generated US$225.6 million of revenue in H1 2022, compared to US$138.2 million for the same period in 2021, an increase of 63%. The increase of US$87.4 million is due to:

-- The PenMal Assets generating US$48.3 million of crude oil revenue (H1 2021: nil) and US$1.9 million of gas revenue (H1 2021: nil) in H1 2022, following completion of the acquisition in August 2021;

-- Higher average realised oil prices at Montara of US$106.76 bbl (H1 2021: US$66.66 bbl) and Stag at US$128.13 bbl (H1 2021: US$70.87 bbl) in H1 2022, contributing an additional US$68.0 million; partly offset by

-- A lower lifted volume by 452,795 bbls at Montara and Stag, representing an estimated decrease of US$30.6 million between the comparable periods.

Production costs

Production costs in H1 2022 were US$83.4 million (H1 2021: US$62.5 million), an increase of US$20.9 million, predominately due to the acquisition of the PenMal Assets which contributed US$24.7 million, and a reduction of US$3.8 million at Montara and Stag. Production costs included:

-- The PenMal Assets incurred US$16.7 million (H1 2021: nil) of Malaysian supplementary payments, due to the realised price exceeding the escalated base price incorporated into the PSC terms;

-- Repair and maintenance ("R&M") costs of US$25.3 million, compared to US$12.1 million in H1 2021. The PenMal Assets incurred routine maintenance of US$2.7 million (H1 2021: nil), Stag an additional US$4.6 million on structural marine maintenance and import hose replacement and Montara an additional US$5.9 million predominately on Skua 11 well subsurface repairs;

-- Operational costs at US$32.6 million, an increase of US$8.3 million compared to H1 2021, predominately associated with the PenMal Assets;

-- Logistics costs increased by US$5.1 million, with the PenMal Assets incurring US$2.6 million (H1 2021: nil). Australia increased by US$2.5 million due to higher fuel costs for operating vessels and helicopters;

-- Transportation costs of US$2.9 million (H1 2021: US$0.5 million), predominately associated with the PenMal Assets and Stag offtake arrangements;

   --      Workover costs reduced by US$1.6 million due to differences in the phasing of workovers; 

-- The PenMal Assets were in an underlift carried forward position of 130,359 bbls (H1 2021: nil) resulting in a production credit of US$9.9 million at the end of H1 2022; and

-- Montara and Stag generated a credit net inventory movement of US$8.5 million, reflecting the increase in closing crude balances compared to the beginning of the period.

Unit operating costs per boe were US$25.71 bbl (H1 2021: US$28.16/bbl) before workovers and movement in inventories but including lease payments and taking into account various other adjustments (see IFRS measures below).

Depletion, depreciation and amortisation ("DD&A")

The depletion charges of oil and gas properties were US$35.1 million in H1 2022, compared to US$39.7 million in H1 2021.

The depletion cost on a unit basis was US$12.06/boe in H1 2022 (H1 2021: US$15.70/bbl), predominately due to the inclusion of the PenMal Assets at US$1.61/boe which benefitted from the low cost base following the acquisition, thus lowering the weighted average DD&A unit charge. Stag and Montara increased over the comparable period by US$2.63/bbl and US$1.71/bbl, respectively, reflecting the completion of development projects and natural decline of the production profile.

Other expenses

Other expenses represent the Group's general and administrative ("G&A") costs, one-off project costs and other miscellaneous expenditures. Total other expenses decreased by US$7.0 million in H1 2022 to US$5.5 million (H1 2021: US$12.5 million) due to lower G&A, one-off project costs and hedging losses incurred in H1 2021.

Other income

Other income was US$ 5.6 million in H1 2022, an increase of US$1.9 million (H1 2021: US$3.7 million). The increase was mainly due to a refund of interest paid to the Australian Taxation Office as part of an early repayment of outstanding 2019 tax amounts previously deferred under a COVID-19 arrangement.

Taxation

The tax charge of US$37.8 million in H1 2022 (H1 2021: US$8.7 million) was split between a current tax charge of US$34.9 million (H1 2021: US$8.9 million) and a deferred tax charge of US$2.8 million (H1 2021: credit of US$0.2 million).

The current tax charge included US$29.2 million (H1 2021: US$11.4 million) of Australian corporate tax plus Malaysian Petroleum Income Tax ("PITA") tax of US$5.9 million (H1 2021: nil), offset by a net Australian Petroleum Resource Rent tax ("PRRT") credit of US$0.2 million (H1 2021: US$2.5 million).

Australian PRRT

Australian PRRT is a cash-based tax charged to petroleum operations at the rate of 40% and deductible from income tax. The current tax credit of US$0.2 million is associated with Stag operations, due to the utilisation of carried forward PRRT losses.

Montara is not anticipated to incur PRRT expense in the future, as it has unutilised PRRT carried forward credits of US$3.4 billion (H1 2021: US$3.3 billion). Based on management's latest forecasts, the historical accumulated PRRT net losses will more than offset PRRT that would arise on future PRRT taxable profits.

Malaysian PITA

Malaysia PITA is imposed at the rate of 38% on income from petroleum operations in Malaysia, no other taxes are imposed on income from petroleum operations.

Deferred tax

The deferred tax movement during the period reflects timing differences for corporate tax, PITA and PRRT. The Group incurred a deferred tax charge of US$2.8 million in H1 2022 (H1 2021: credit of US$0.3 million), because of timing differences between the PITA tax and accounting treatment of the Malaysian crude under-lift position of US$3.6 million (H1 2021: nil) and a deferred tax credit in Australia of US$0.8 million from the timing differences of the accounting and tax bases of the oil and gas properties .

H1 2022 RECONCILIATION OF CASH

 
                                                 US$'000    US$'000 
---------------------------------------------  ---------  --------- 
 
 Total cash and cash equivalent, 31 December 
  2021                                                      117,865 
 Revenue                                         225,639 
 Other operating income                            3,524 
 Production costs                               (83,401) 
 Administrative staff costs                     (14,482) 
 General and administrative expenses             (4,799) 
 Operating cash flows before movements 
  in working capital                                        126,481 
 Movements in working capital                              (22,658) 
 Net tax paid                                              (34,177) 
 Interest paid                                                (600) 
 Purchases of intangible exploration assets, 
  oil and gas properties, and 
  plant and equipment(1)                                   (13,364) 
 Other investing activities                                     170 
 Financing activities                                      (12,089) 
                                                          --------- 
 
 Total cash and cash equivalent, 30 June 
  2022                                                      161,628 
                                                          ========= 
 

NON-IFRS MEASURES

The Group uses certain performance measures that are not specifically defined under IFRS, or other generally accepted accounting principles. These non-IFRS measures comprise operating cost per barrel of oil equivalent (opex/boe), adjusted EBITDAX and net cash.

The following notes describe why the Group has selected these non-IFRS measures.

(1) Total capital expenditure was US$13.6 million, comprising total capital expenditure paid of US$13.4 million, plus accrued capital expenditure of US$0.2 million.

Operating costs per barrel of oil equivalent (Opex/boe)

Opex/boe is a non-IFRS measure used to monitor the Group's operating cost efficiency, as it measures operating costs to extract hydrocarbons from the Group's producing reservoirs on a unit basis.

Opex/boe is defined as total production costs excluding crude inventories movement, underlift/overlift, workovers (to facilitate better comparability period to period), non-recurring R&M, supplementary payments, DD&A, transportation, and short term COVID-19 incentives. It includes lease payments related to operational activities, net of any income earned from right-of-use assets involved in production.

The adjusted production cost is divided by total produced barrels of oil equivalent for the prevailing period to determine the unit operating cost per boe.

 
                                            Six months   Six months         Twelve 
                                                 ended        ended   months ended 
                                               30 June      30 June    31 December 
  USD'000 except where indicated                  2022         2021           2021 
----------------------------------------   -----------  -----------  ------------- 
 
Production costs (reported)                     83,401       62,492        206,523 
Adjustments 
Lease payments related to 
 operating activities(1)                         6,371        6,444         10,619 
Underlift, overlift and crude 
 inventories 
 movement(2)                                    18,412      (5,642)        (9,680) 
Workover costs(3)                              (8,435)     (10,027)       (67,006) 
Other income(4)                                (2,410)      (2,286)        (4,512) 
Non-recurring repair and maintenance(5)        (5,510)            -        (6,593) 
Australian transportation 
 costs                                           (510)        (541)        (1,231) 
PenMal Assets supplementary 
 payments(6)                                  (16,731)            -        (8,255) 
Australian Government JobKeeper 
 scheme                                              -          196            196 
PenMal non-operated assets 
 FPSO rectification 
 costs(7)                                      (4,748)            -              - 
 
Adjusted production costs                       69,840       50,636        120,061 
                                           -----------  -----------  ------------- 
 
Total production (barrels 
 of oil equivalent)                          2,716,436    1,797,989      4,578,962 
 
Operating costs per barrel 
 of oil equivalent                               25.71        28.16          26.22 
                                           ===========  ===========  ============= 
 

(1) Lease payments related to operating activities are payments considered to be operating costs in nature, including leased helicopters for transporting offshore crews.

(2) Underlift, overlift and crude inventories movement are added back to the calculation to match the full cost of production with the associated production volumes (i.e., numerator to match denominator).

(3) Workover costs are excluded to enhance comparability. The frequency of workovers can vary significantly, across periods.

(4) Other income represents the rental income from a helicopter rental contract (a right-of-use asset) to a third party.

(5) Non-recurring repair and maintenance costs in H1 2022 related to the Montara Skua 11 well subsurface repairs and Stag structural marine maintenance and import hose replacement. The costs from the year ended 2021 related to the Montara Swift North SCM change out and facility integrity baseline survey.

(6) The supplementary payments are required under the terms of PSCs based on Jadestone's profit oil after entitlements between the government and joint venture partners.

(7) PenMal non-operated assets FPSO rectification costs refer to the costs incurred to repair the FPSO BUK CLASS at PM318 and AAKBNLP PSCs following its suspension in February 2022.

Adjusted EBITDAX

Adjusted EBITDAX is a non-IFRS measure which does not have a standardised meaning prescribed by IFRS. This non-IFRS measure is included because management uses the information to analyse cash generation and financial performance of the Group.

Adjusted EBITDAX is defined as profit from continuing activities before income tax, finance costs, interest income, DD&A, other financial gains, non-recurring expenses and exploration assets write-offs.

The calculation of adjusted EBITDAX is as follows:

 
                                        Six months   Six months          Twelve 
                                             ended        ended    months ended 
                                           30 June      30 June     31 December 
   USD'000                                    2022         2021            2021 
 
 Revenue                                   225,639      138,158         340,194 
 Production costs                         (83,401)     (62,492)       (206,523) 
 Administrative staff costs               (15,165)     (12,067)        (25,068) 
 Other expenses                            (5,503)     (12,501)        (26,181) 
 Other income, excluding interest 
  income                                     3,528        3,643           7,602 
 Other financial gains                           -            -             266 
                                       -----------  -----------  -------------- 
 
 Unadjusted EBITDAX                        125,098       54,741          90,290 
 
 Non-recurring 
 Net loss from oil price derivatives             -        4,633           4,633 
 Non-recurring opex(1)                      13,135        1,574          53,096 
 Intangible exploration assets 
  written off                                    -            -           5,260 
 Loss on contingent considerations               -            -             438 
 Other                                         375        4,231           4,231 
                                       -----------  -----------  -------------- 
 
                                            13,510       10,438          67,658 
                                       -----------  -----------  -------------- 
 
 Adjusted EBITDAX                          138,608       65,179         157,948 
                                       ===========  ===========  ============== 
 

(1) Non-recurring opex represents one-off major maintenance/well intervention activities, in particular the Montara Skua 11 well subsurface repairs and Stag structural marine maintenance and import hose replacement . The H1 2021 non-recurring costs mainly consisted of workover campaigns at Skua 10 & 11, while Swift North SCM change out and facility integrity baseline survey were included in the 2021 full year costs.

Net cash

Net cash is a non-IFRS measure which does not have a standardised meaning prescribed by IFRS. Management uses this measure to analyse the financial strength of the Group. The measure is used to ensure capital is managed effectively in order to support its ongoing operations, and to raise additional funds, if required.

 
                                30 June   30 June  31 December 
    USD'000                        2022      2021         2021 
---------------------------   ---------  --------  ----------- 
 
Cash and cash equivalents, 
 representing net 
 cash of the Group              161,628    48,291      117,865 
                              =========  ========  =========== 
 

The cash and cash equivalents for the period ended 30 June 2021 includes restricted cash of US$1.0 million associated with an Indonesian performance bond that was returned in Q3 2021.

2022 PRINCIPAL FINANCIAL RISKS AND UNCERTAINTIES

The Group manages principal risks and uncertainties via its risk management framework. The Group is exposed to a variety of political, technological, environmental, operational and financial risks which are monitored and/or mitigated to acceptable levels.

The Group's risk management framework provides a systematic process for the identification of the principal risks which have the possibility of impacting the Group's strategic objectives. The Board regularly reviews the principal risks and defines corporate targets based on acceptable levels of risk. The Board assesses material risks quarterly with a full review of the risk matrix at least twice per year.

Details of the principal risks and uncertainties faced by the Group as at 30 June 2022 remain unchanged from the risks disclosed in the 2021 Annual Report pages 57 to 63. The Group's risk mitigation activities also remain unchanged.

GOING CONCERN

The Directors have adopted the going concern basis in preparing these unaudited condensed consolidated interim financial statements, having considered the principal financial risks and uncertainties of the Group.

The Directors believe that the Group is well placed to manage its financing and other business risks satisfactorily. The Directors have a reasonable expectation that the Group will have adequate resources to continue in operation for at least 18 months from the date of these unaudited condensed consolidated interim financial statements. They therefore consider it appropriate to adopt the going concern basis of accounting in preparing these financial statements.

STATEMENT OF DIRECTORS' RESPONSIBILITIES

The Directors confirm that to the best of their knowledge:

a. the condensed consolidated interim set of financial statements has been prepared in accordance with IAS 34 Interim Financial Reporting ;

b. the interim management report includes a fair review of the information required by DTR 4.2.7R (indication of important events during the first six months and description of principal risks and uncertainties for the remaining six months of the year); and

c. the interim management report includes a true and fair review of the information required by DTR 4.2.8R (disclosure of related parties' transactions and changes therein).

By order of the Board,

Paul Blakeley

Executive Director

President & Chief Executive Officer

20 September 2022

Condensed Consolidated Statement of Profit or Loss and Other Comprehensive Income

for the six months ended 30 June 2022

 
                                              Six months   Six months          Twelve 
                                                   ended        ended    months ended 
                                                 30 June      30 June     31 December 
                                                    2022         2021            2021 
                                               Unaudited    Unaudited         Audited 
                                      Notes      USD'000      USD'000         USD'000 
-----------------------------------  ------  -----------  -----------  -------------- 
 
 Consolidated statement 
  of profit or loss 
 Revenue                                         225,639      138,158         340,194 
 Production costs                       5       (83,401)     (62,492)       (206,523) 
 Depletion, depreciation 
  and amortisation                      5       (35,135)     (39,697)        (80,215) 
 Administrative staff costs                     (15,165)     (12,067)        (25,068) 
 Other expenses                         5        (5,503)     (12,501)        (26,181) 
 Other income                                      5,602        3,681           7,682 
 Finance costs                          6        (4,784)      (3,934)         (9,075) 
 Other financial gains                                 -            -             266 
                                             -----------  -----------  -------------- 
 
 Profit before tax                                87,253       11,148           1,080 
 Income tax expense                     7       (37,767)      (8,653)        (14,822) 
                                             -----------  -----------  -------------- 
 
 Profit/(Loss) for the 
  period/year, 
  representing total comprehensive 
  income 
  for the year                                    49,486        2,495        (13,742) 
                                             ===========  ===========  ============== 
 
 Earnings/(Loss) per ordinary 
  share 
 Basic (US$)                            8           0.11         0.01          (0.03) 
                                             ===========  ===========  ============== 
 
 Diluted (US$)                                      0.10         0.01          (0.03) 
                                             ===========  ===========  ============== 
 

Condensed Consolidated Statement of Financial Position as at 30 June 2022

 
                                               30 June     30 June   31 December 
                                                  2022        2021          2021 
                                             Unaudited   Unaudited       Audited 
                                     Notes     USD'000     USD'000       USD'000 
----------------------------------  ------  ----------  ----------  ------------ 
 
 Assets 
 
 Non-current assets 
 Intangible exploration 
  assets                               9        77,027      96,443        93,241 
 Oil and gas properties               10       350,404     303,625       353,592 
 Plant and equipment                  10         8,896       1,584         8,963 
 Right-of-use assets                  10         9,288      18,358        13,852 
 Other receivables and prepayment     11        46,817       4,451        48,500 
 Deferred tax assets                            14,366      16,318        25,278 
                                            ----------  ----------  ------------ 
 
 Total non-current assets                      506,798     440,779       543,426 
                                            ----------  ----------  ------------ 
 
 Current assets 
 Inventories                                    38,162      34,812        23,299 
 Trade and other receivables          11        28,588      63,135        37,951 
 Tax recoverable                       7         8,162           -         9,367 
 Restricted cash                                     -       1,000             - 
 Cash and cash equivalents                     161,628      47,291       117,865 
                                            ----------  ----------  ------------ 
 
 Total current assets                          236,540     146,238       188,482 
                                            ----------  ----------  ------------ 
 
 Total assets                                  743,338     587,017       731,908 
                                            ==========  ==========  ============ 
 
 Equity and liabilities 
 
 Equity 
 
 Capital and reserves 
 Share capital                        12         1,229         391           559 
 Share based payments reserve                   26,619      25,625        25,936 
 Merger reserve                       14       146,270     146,270       146,270 
 Retained earnings/(Accumulated 
  losses)                                       11,553    (12,710)      (31,692) 
                                            ----------  ----------  ------------ 
 
 Total equity                                  185,671     159,576       141,073 
                                            ----------  ----------  ------------ 
 
 Non-current liabilities 
 Provisions                           15       413,451     290,693       410,697 
 Lease liabilities                               1,154       9,086         4,504 
 Deferred tax liabilities                       59,032      54,564        67,097 
                                            ----------  ----------  ------------ 
 
 Total non-current liabilities                 473,637     354,343       482,298 
                                            ----------  ----------  ------------ 
 
 
 
 
 
 
                                               30 June     30 June   31 December 
                                                  2022        2021          2021 
                                             Unaudited   Unaudited       Audited 
                                     Notes     USD'000     USD'000       USD'000 
----------------------------------  ------  ----------  ----------  ------------ 
 
 Current liabilities 
 Lease liabilities                               9,576      11,625        11,161 
 Trade and other payables             16        46,575      22,760        69,090 
 Provisions                           15         3,503       3,091         1,947 
 Tax liabilities                       7        24,376      35,622        26,339 
                                            ----------  ----------  ------------ 
 
 Total current liabilities                      84,030      73,098       108,537 
                                            ----------  ----------  ------------ 
 
 Total liabilities                             557,667     427,441       590,835 
                                            ----------  ----------  ------------ 
 
 Total equity and liabilities                  743,338     587,017       731,908 
                                            ==========  ==========  ============ 
 

Condensed Consolidated Statement of Changes in Equity

for the six months ended 30 June 2022

 
                                   Non-distributable 
                                             reserve 
                                               Share 
                                               based    Distributable reserves 
                           Share            payments     Merger     Accumulated 
                         capital             reserve    reserve          losses      Total 
                         USD'000            USD"000    USD'000         USD'000    USD'000 
--------------------  ----------  ------------------  ---------  --------------  --------- 
 
 As at 1 January 
  2021                   466,979              24,985          -       (331,322)    160,642 
 
 Profit for 
  the period, 
  representing 
  total 
  comprehensive 
  income for 
  the 
  period                       -                   -          -           2,495      2,495 
                      ----------                      ---------  --------------  --------- 
 
 Dividend paid                 -                   -          -         (5,000)    (5,000) 
 Share-based 
  compensation                 -                 640          -               -        640 
 Shares issued               799                   -          -               -        799 
 Capital reduction     (467,387)                   -    146,270         321,117          - 
                                  ------------------  --------- 
 
 Total transactions 
  with owners, 
  recognised 
  directly 
  in equity            (466,588)                 640    146,270         316,117    (3,561) 
                      ----------  ------------------  ---------  --------------  --------- 
 
 As at 30 June 
  2021                       391              25,625    146,270        (12,710)    159,576 
                      ==========  ==================  =========  ==============  ========= 
 
 As at 1 January 
  2021                   466,979              24,985          -       (331,322)    160,642 
 
 Loss for the 
  year, 
  representing 
  total 
  comprehensive 
  income for 
  the year                     -                   -          -        (13,742)   (13,742) 
                      ----------                                 --------------  --------- 
 
 Capital reduction     (467,387)                   -    146,270         321,117          - 
 Dividend paid                 -                   -          -         (7,745)    (7,745) 
 Share-based 
  compensation                 -                 951          -               -        951 
 Shares issued               967                   -          -               -        967 
                      ----------  ------------------  ---------  --------------  --------- 
 
 Total transactions 
  with owners, 
  recognised 
  directly 
  in equity            (466,420)                 951    146,270         313,372    (5,827) 
                      ----------                                 --------------  --------- 
 
 As at 31 December 
  2021                       559              25,936    146,270        (31,692)    141,073 
                      ==========  ==================  =========  ==============  ========= 
 
 
                                   Non-distributable 
                                             reserve    Distributable reserves 
                                               Share               (Accumulated 
                                               based                   losses)/ 
                           Share            payments     Merger        Retained 
                         capital             reserve    reserve        earnings      Total 
                         USD'000            USD"000    USD'000         USD'000    USD'000 
--------------------  ----------  ------------------  ---------  --------------  --------- 
 
 As at 1 January 
  2022                       559              25,936    146,270        (31,692)    141,073 
 
 Profit for 
  the period, 
  representing 
  total 
  comprehensive 
  income for 
  the 
  period                       -                   -          -          49,486     49,486 
                      ----------  ------------------  ---------  --------------  --------- 
 
 Dividend paid                 -                   -          -         (6,241)    (6,241) 
 Share-based 
  compensation                 -                 683          -               -        683 
 Shares issued               670                   -          -               -        670 
                                  ------------------  --------- 
 
 Total transactions 
  with owners, 
  recognised 
  directly 
  in equity                  670                 683          -         (6,241)    (4,888) 
                      ----------  ------------------  ---------  --------------  --------- 
 
 As at 30 June 
  2022                     1,229              26,619    146,270          11,553    185,671 
                      ==========  ==================  =========  ==============  ========= 
 

Condensed Consolidated Statement of Cash Flows for the six months ended 30 June 2022

 
                                               Six months   Six months        Twelve 
                                                                              months 
                                                    ended        ended         ended 
                                                  30 June      30 June   31 December 
                                                     2022         2021          2021 
                                                Unaudited    Unaudited       Audited 
                                       Notes      USD'000      USD'000       USD'000 
------------------------------------  ------  -----------  -----------  ------------ 
 
 Operating activities 
 Profit before tax                                 87,253       11,148         1,080 
 Adjustments for: 
  Depletion, depreciation 
   and amortisation                      5         28,988       33,338        69,024 
  Depreciation of right-of-use          5 / 
   assets                                10         6,147        6,359        11,191 
  Other finance costs                    6          4,643        3,784         8,487 
  Share-based payments                                683          640           951 
  Provision for doubtful 
   debts                                              446          201             - 
  Unrealised foreign exchange 
   loss/(gain)                                        241        (735)       (1,838) 
  Interest expense                       6            141          150           150 
  Assets written off                                   13            -         5,332 
  Interest income                                 (2,074)         (38)          (80) 
  Reversal of fair value 
   loss on oil derivatives                              -        (471)         (471) 
  Accretion income on non-current 
   VAT 
   receivables                                          -            -         (266) 
  Change in fair value of 
   contingent payments                                  -            -           438 
  Allowance for slow moving 
   inventories                                          -            -         2,624 
 
 Operating cash flows before 
  movements in 
  working capital                                 126,481       54,376        96,622 
 
 Decrease/(Increase) in trade 
  and other 
  receivables                                      10,505     (53,777)      (11,975) 
 (Increase)/Decrease in inventories              (10,774)        5,719         9,152 
 (Decrease)/Increase in trade 
  and other 
  payables                                       (22,389)      (5,196)        21,631 
                                              -----------  -----------  ------------ 
 
 Cash generated from operations                   103,823        1,122       115,430 
 
 Interest paid                                      (600)        (768)       (1,505) 
 Tax refunded                                          12            -         3,652 
 Tax paid                                        (34,189)      (8,004)      (15,486) 
                                              -----------  -----------  ------------ 
 
 Net cash generated/(used 
  in) from operating 
  activities                                       69,046      (7,650)       102,091 
                                              -----------  -----------  ------------ 
 
 
 
 
 
 
 
 
 
 
                                               Six months   Six months        Twelve 
                                                                              months 
                                                    ended        ended         ended 
                                                  30 June      30 June   31 December 
                                                     2022         2021          2021 
                                                Unaudited    Unaudited       Audited 
                                       Notes      USD'000      USD'000       USD'000 
------------------------------------  ------  -----------  -----------  ------------ 
 
 Investing activities 
 Cash received from acquisition 
  of Peninsular 
  Malaysia assets                                       -            -        29,252 
 Cash paid for acquisition 
  of Peninsular 
  Malaysia assets                                       -            -      (20,033) 
 Payment for oil and gas 
  properties                            10       (10,687)     (14,173)      (51,380) 
 Payment for plant and equipment        10          (253)        (216)         (682) 
 Payment for intangible exploration 
  assets                                 9        (2,424)      (1,476)       (3,858) 
 Transfer from debt service 
  reserve account                                       -        7,445         8,445 
 Interest received                                    170           38            80 
                                              -----------  -----------  ------------ 
 
 Net cash used in investing 
  activities                                     (13,194)      (8,382)      (38,176) 
                                              -----------  -----------  ------------ 
 
 Financing activities 
 Net proceeds from issuance 
  of shares                                           670          799           967 
 Dividends paid                                   (6,241)      (5,000)       (7,745) 
 Repayment of borrowings                                -      (7,356)       (7,296) 
 Repayment of lease liabilities                   (6,518)      (6,116)      (12,972) 
 
 Net cash used in financing 
  activities                                     (12,089)     (17,673)      (27,046) 
                                              -----------  -----------  ------------ 
 
 Net increase/(decrease) 
  in cash and cash 
  equivalents                                      43,763     (33,705)        36,869 
 
 Cash and cash equivalents 
  at beginning of the 
  period/year                                     117,865       80,996        80,996 
                                              -----------  -----------  ------------ 
 
 Cash and cash equivalents 
  at end of the 
  period/year                                     161,628       47,291       117,865 
                                              ===========  ===========  ============ 
 

Explanation Notes to the Condensed Consolidated Interim Financial Statements

for the six months ended 30 June 2022

   1.    GENERAL INFORMATION 

Jadestone Energy plc (the "Company" or "Jadestone") is an oil and gas company incorporated in the United Kingdom and registered in England and Wales. The company registration number is 13152520 and the Company's shares are traded on AIM under the symbol "JSE".

The financial statements are expressed in United States Dollars.

The Group is engaged in production, development, exploration and appraisal activities in Australia, Malaysia, Vietnam and Indonesia. The Group's producing assets are in the Vulcan (Montara) and Carnarvon (Stag) basins, located in shallow water offshore of Western Australia, and in the East Piatu, East Belumut, West Belumut and Chermingat fields, located in shallow water offshore Peninsular Malaysia.

The Company's head office is located at 3 Anson Road, #13-01 Springleaf Tower, Singapore 079909. The registered office of the Company is Suite 1, 3rd Floor, 11 - 12 St James's Square, London SW1Y 4LB.

These financial statements were authorised for issue and release by the Company's Board of Directors on 20 September 2022.

   2.    SIGNIFICANT EVENT DURING THE PERIOD 

Montara operations update

On 17 June 2022, between three to five cubic metres of crude oil was released to sea during a routine oil transfer between tanks on the Montara Venture FPSO. The facility was immediately shut-in as a precaution and the relevant authorities notified. Following a temporary repair and isolation of the 2C tank, production was restarted on 4 July 2022 while a permanent repair was being developed.

On 12 August 2022, an additional defect was identified in a ballast water tank on the Montara Venture FPSO during preparation work for a permanent repair to the 2C tank. The Group took the decision to temporarily shut-in production at Montara to prioritise the permanent repairs due to an inability to simultaneously accommodate production and inspection and repair crews.

   3.    SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES 

BASIS OF PREPARATION

These unaudited condensed consolidated interim financial statements (the "financial statements") are prepared in accordance with International Accounting Standard IAS 34 Interim Financial Reporting, as adopted by the European Union, on a going concern basis under the historical cost convention.

These unaudited condensed consolidated interim financial statements do not comprise statutory accounts within the meaning of section 435 of the Companies Act 2006 ("the Act"). They do not contain all disclosures required by IFRS for annual financial statements and should be read in conjunction with Jadestone's audited consolidated financial statements for the year ended 31 December 2021. Jadestone's auditors reported on those accounts; their report was unqualified and did not draw attention to any matters by way of emphasis.

These financial statements have been prepared on an historical cost basis, except for financial instruments classified as financial instruments at fair value, which are stated at their fair values, and operating leases which are stated at the present value of future cash payments.

In addition, these financial statements have been prepared using the accrual basis of accounting.

GOING CONCERN

As at 30 June 2022, the Group has a total cash and cash equivalents of US$161.6 million, and the Group managed to keep the cash levels within the range of US$110.0 - 160.0 million between July and August 2022, after the settlements of trade related expenditure. The average Dated Brent crude price in July and August 2022 was US$102.73/bbl, largely aligned with the average price during the first half of 2022. Hence the Group was able to continue to generate material cash inflows from the liftings in Australia and Malaysia subsequent to June 2022 end.

The Group regularly monitors its cash, funding and liquidity position. Near term cash projections are revised and underlying assumptions reviewed, generally monthly, and longer-term projections are also updated regularly. All principal risk and uncertainties faced by the Group are disclosed in the 2021 Annual Report pages 57 to 63 and have been considered in the Group's near and longer term cash projections. The principal risk and uncertainties remain unchanged at the current period end. For the purposes of the Group's going concern assessment, we have reviewed cash projections for the period from 1 July 2022 to 31 December 2023, the 'going concern period'.

Having taken into consideration the above factors, the Directors have reasonable expectation that the Group has adequate resources to continue in operational existence for the going concern period. Accordingly, they adopted the going concern basis in preparing these unaudited condensed consolidated interim financial statements.

Adoption of new and revised standards

New and amended IFRS standards that are effective for the current period

The Group has applied the following amendment that is relevant to the Group for the first time with effect from 1 January 2022.

   -          Amendments to IAS 37    Onerous Contracts - Cost of Fulfilling a Contract 
   -          Amendments to IFRS 3     Reference to Conceptual Framework 
   -          Amendments to IFRSs      Annual Improvements to IFRS Standards 2018 - 2020 

The amendments are effective for annual periods beginning on 1 January 2022 and require prospective application. The adoption of these amendments has not resulted in changes to the Group's accounting policies.

4. CRITICAL ACCOUNTING JUDGMENTS AND KEY SOURCES OF ESTIMATION UNCERTAINTY

Climate change and energy transition

The Group has assessed the potential impacts of climate change and the transition to a lower carbon economy in preparing these financial statements. The Group's assumptions relating to demand for oil and gas and their impact on the Group's long-term price assumptions remain the same as disclosed in the Jadestone's audited consolidated financial statements for the year ended 31 December 2021. The Group also takes into consideration the forecasted long-term prices and demand for oil and gas under the Paris aligned scenarios. The forecasted long-term prices and demand for oil and gas under the Paris aligned scenarios remain the same as disclosed in Jadestone's audited consolidated financial statements for the year ended 31 December 2021 .

Details of the Group's environment, social and governance ("ESG") plans and activities are disclosed in the 2021 Annual Report pages 26 to 49 and the ESG section above.

Critical accounting judgments and key sources of estimation uncertainty

In the application of the Group's accounting policies, management is 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 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 key judgements and sources of estimation uncertainty remain the same as disclosed in Jadestone's audited consolidated financial statements for the year ended 31 December 2021 .

5. OPERATING COSTS

 
                                   Six months   Six months          Twelve 
                                        ended        ended    months ended 
                                      30 June      30 June     31 December 
                                         2022         2021            2021 
                                    Unaudited    Unaudited         Audited 
                                      USD'000      USD'000         USD'000 
-------------------------------   -----------  -----------  -------------- 
 
 Production costs                      80,533       61,951         203,714 
 Tariffs and transportation 
  costs                                 2,868          541           2,809 
                                  -----------  -----------  -------------- 
 
 Total production costs                83,401       62,492         206,523 
                                  ===========  ===========  ============== 
 
 Depletion and amortisation 
  of oil and 
  gas properties                       28,681       33,054          68,516 
 Depreciation of plant 
  equipment and 
  right-of-use assets                   6,454        6,643          11,699 
                                  -----------  -----------  -------------- 
 
 Total depletion, depreciation 
  and 
  amoritisation                        35,135       39,697          80,215 
                                  ===========  ===========  ============== 
 
 Corporate costs                        5,057       12,230          21,548 
 Other operating expenses                 446          271           4,633 
                                  -----------  -----------  -------------- 
 
 Total other expenses                   5,503       12,501          26,181 
                                  ===========  ===========  ============== 
 
   6.    FINANCE COSTS 
 
                          Six months   Six months        Twelve 
                               ended        ended        months 
                                                          ended 
                             30 June      30 June   31 December 
                                2022         2021          2021 
                           Unaudited    Unaudited       Audited 
                             USD'000      USD'000       USD'000 
----------------------   -----------  -----------  ------------ 
 
 Interest expense and 
  others                         600        1,465         3,155 
 Accretion expense             4,184        2,469         5,920 
 
                               4,784        3,934         9,075 
                         ===========  ===========  ============ 
 
   7.    INCOME TAX EXPENSE 
 
                                    Six months  Six months        Twelve 
                                         ended       ended        months 
                                       30 June     30 June         ended 
                                          2022        2021   31 December 
                                     Unaudited   Unaudited          2021 
                                       USD'000     USD'000       Audited 
                                                                 USD'000 
---------------------------------   ----------  ----------  ------------ 
 
 Current tax 
   Corporate tax charge/(credit)        29,154      11,405         (486) 
   Overprovision in prior 
    year                                     -           -         (270) 
                                    ----------  ----------  ------------ 
 
                                        29,154      11,405         (756) 
   Australian petroleum resource 
    rent 
    tax ("PRRT")                         (162)     (2,496)       (1,374) 
   Malaysian petroleum income 
    tax 
    ("PITA")                             5,928           -         9,469 
 
                                        34,920       8,909         7,339 
                                    ----------  ----------  ------------ 
 
 Deferred tax 
   Corporate tax                       (4,042)     (3,033)         5,247 
   PRRT                                  3,244       2,777         3,371 
   PITA                                  3,645           -       (1,135) 
                                    ==========  ==========  ============ 
 
                                         2,847       (256)         7,483 
                                    ----------  ----------  ------------ 
 
                                        37,767       8,653        14,822 
                                    ==========  ==========  ============ 
 
   8.    EARNINGS/(LOSS) PER ORDINARY SHARE 

The calculation of the basic and diluted earnings/(loss) per share is based on the following data:

 
                             Six months   Six months        Twelve 
                                  ended        ended        months 
                                                             ended 
                                30 June      30 June   31 December 
                                   2022         2021          2021 
                              Unaudited    Unaudited       Audited 
                                USD'000      USD'000       USD'000 
-------------------------   -----------  -----------  ------------ 
 
 Profit/(Loss) for the 
  purposes of basic 
  and diluted per share, 
  being the net 
  profit for the period 
  attributable to 
  equity holders of the 
  Company                        49,486        2,495      (13,742) 
                            ===========  ===========  ============ 
 
 
                                       Number        Number        Number 
------------------------------   ------------  ------------  ------------ 
 
 Weighted average number 
  of ordinary 
  shares for the purposes 
  of basic EPS                    465,485,869   462,894,872   463,567,519 
 Effect of dilutive potential 
  ordinary 
  shares - share options            6,029,827     6,100,692             - 
 Effect of dilutive potential 
  ordinary 
  shares - performance 
  shares                              595,998             -             - 
 Effect of dilutive potential 
  ordinary 
  shares - restricted 
  shares                              178,887             -             - 
                                 ------------  ------------  ------------ 
 
 Weighted average number 
  of ordinary 
  shares for the purposes 
  of diluted EPS                  472,290,581   468,995,564   463,567,519 
                                 ============  ============  ============ 
 

The calculation of diluted EPS for the six months ended 30 June 2022 includes 6,029,827 of weighted average dilutive ordinary shares available for exercise from in-the-money vested options (six months ended 30 June 2021: 6,100,692).

The calculation of diluted EPS for the six months ended 30 June 2022 includes 595,998 of weighted average contingently issuable shares associated under the Company's performance share plan based on the respective performance measures up to the period end (six months ended 30 June 2021: nil).

The calculation of diluted EPS for the six months ended 30 June 2022 includes 178,887 of weighted average contingently issuable shares under the Company's restricted share plan (six months ended 30 June 2021: nil).

 
                             Six months  Six months         Twelve 
                                  ended       ended   months ended 
                                30 June     30 June    31 December 
                                   2022        2021           2021 
Earnings/(Loss) per share     Unaudited   Unaudited        Audited 
 (US$) 
 
 
  *    Basic                       0.11        0.01         (0.03) 
                             ==========  ==========  ============= 
- 
 
  *    Diluted                     0.10        0.01         (0.03) 
                             ==========  ==========  ============= 
 
   9.    INTANGIBLE EXPLORATION ASSETS 
 
                                                         Total 
                                                       USD'000 
--------------------------------------------------  ---------- 
 
 Cost 
 As at 1 January 2021                                  151,125 
 Additions                                               1,832 
 Reversal                                              (6,059) 
 Written off                                          (50,455) 
                                                    ---------- 
 
 As at 30 June 2021                                     96,443 
 Additions                                               2,102 
 Changes in asset retirement obligations                  (44) 
 Written off                                           (5,260) 
 
 As at 31 December 2021                                 93,241 
 Additions                                               2,681 
 Reclassification                                    (18,895)* 
                                                    ---------- 
 
 As at 30 June 2022                                     77,027 
                                                    ========== 
 
 Impairment 
 As at 1 January 2021                                   50,455 
 Additions                                            (50,455) 
                                                    ---------- 
 
 As at 30 June 2021/31 December 2021/30 June 2022            - 
                                                    ========== 
 
 Net book value 
 As at 30 June 2021 (unaudited)                         96,443 
                                                    ========== 
 
 As at 31 December 2021 (audited)                       93,241 
                                                    ========== 
 
 As at 30 June 2022 (unaudited)                         77,027 
                                                    ========== 
 

* The reclassification of US$18.9 million relates to the Lemang PSC in Indonesia. On 6 June 2022, the final investment decision was taken following regulatory approval to award the engineering, procurement, construction and installation (" EPCI") contract which established commercial viability. The capitalised cost of US$18.9 million was transferred to development assets as disclosed in Note 10.

   10.          PROPERTY, PLANT AND EQUIPMENT 
 
                              Oil and gas properties 
                           Production        Development                 Plant        Right-of-use 
                               assets             assets         and equipment              assets          Total 
                              USD'000            USD'000               USD'000             USD'000        USD'000 
------------------  ----  -----------  ---  ------------  ---  ---------------  ---  -------------  ---  -------- 
 
 Cost 
 As at 1 January 
  2021                        496,992                  -                 4,612              45,514        547,118 
 Additions                     14,173                  -                   216               1,044         15,433 
                                            ------------ 
 
 As at 30 
  June 2021                   511,165                  -                 4,828              46,558        562,551 
 Changes in 
  asset 
  restoration 
  obligations                  23,894                  -                     -                   -         23,894 
 Acquisition 
  of 
  PenMal Assets                21,744                  -                     -                   -         21,744 
 Additions                     38,691                  -                   466               1,810         40,967 
 Written off                        -                  -                 (169)                   -          (169) 
 Transfer                           -                  -                 7,209                   -          7,209 
                                            ------------ 
 
 As at 31 
  December 
  2021                        595,494                  -                12,334              48,368        656,196 
 Additions                     10,687                  -                   253               1,583         12,523 
 Reclassification                   -             18,895                     -                   -         18,895 
 Written off                  (3,704)                  -                  (67)             (5,981)        (9,752) 
 
 As at 30 
  June 2022                   602,477             18,895                12,520              43,970        677,862 
                          ===========       ============       ===============       =============       ======== 
 
 Accumulated 
  depletion, 
  depreciation 
  and 
  amortisation 
 As at 1 January 
  2021                        179,316                  -                 2,960              21,841        204,117 
 Charge for 
  the period                   28,224                  -                   284               6,359         34,867 
                                            ------------ 
 
 As at 30 
  June 2021                   207,540                  -                 3,244              28,200        238,984 
 Charge for 
  the period                   34,362                  -                   224               6,316         40,902 
 Written off                        -                  -                  (97)                   -           (97) 
                                            ------------ 
 
 As at 31 
  December 
  2021                        241,902                  -                 3,371              34,516        279,789 
 Charge for 
  the period                   32,770                  -                   307               6,147         39,224 
 Written off                  (3,704)                  -                  (54)             (5,981)        (9,739) 
 
 As at 30 
  June 2022                   270,968                  -                 3,624              34,682        309,274 
 
 Net book 
  value 
  As at 30 
  June 2021 
   (unaudited)                303,625                  -                 1,584              18,358        323,567 
 
 As at 31 
  December 
  2021 (audited)              353,592                  -                 8,963              13,852        376,407 
 
  As at 30 
  June 2022 
   (unaudited)                331,509             18,895                 8,896               9,288        368,588 
 
   11.          TRADE AND OTHER RECEIVABLES 
 
                                       30 June    30 June  31 December 
                                          2022       2021         2021 
                                     Unaudited  Unaudited      Audited 
                                       USD'000    USD'000      USD'000 
 
Non-current 
Other receivables 
 At beginning of period/year            41,726          -            - 
 Acquisition of PenMal Assets                -          -       42,092 
 Change in asset restoration 
  obligations                                -          -        (672) 
 Cess paid                                 169          -          306 
 
 At end of period/year                  41,895          -       41,726 
Prepayment                                   -          -        2,000 
VAT receivables                          4,922      4,451        4,774 
 
                                        46,817      4,451       48,500 
 
Current 
Trade receivables                          535     46,291        9,143 
Prepayments                              7,166      6,093        3,770 
Other receivables and deposits           2,175      6,621       13,281 
Amount due from joint arrangement 
 partners (net)                            226          -        2,203 
Underlift crude oil inventories         16,802          -        6,855 
PRRT receivables                           162      2,496            - 
GST/VAT receivables                      1,522      1,634        2,699 
 
                                        28,588     63,135       37,951 
 
                                        75,405     67,586       86,451 
 
   12.          SHARE CAPITAL 
 
                                              No. of      USD'000 
                                              shares 
 
Issued and fully paid 
As at 1 January 2021                     461,842,811      466,979 
Issued during the period                   1,856,666          800 
Capital reduction, at GBP0.499 each                -    (467,388) 
 
As at 30 June 2021                       463,699,477          391 
Issued during the period                   1,381,761          168 
 
As at 31 December 2021                   465,081,238          559 
Issued during the period                     972,378          670 
 
As at 30 June 2022                       466,053,616        1,229 
                                                      =========== 
 

The Company has one class of ordinary share. Fully paid ordinary shares carry one vote per share without restriction, and carry a right to dividends as and when declared by the Company.

   13.          DIVID 

On 6 June 2022, the Directors declared the 2021 final dividend of 1.34 US cents/share, equivalent to 1.07 GB pence/share based on the spot exchange rate of 0.7954 , equivalent to a total distribution of US$ 6.2 million. The dividend was paid on 5 July 2022.

   14.          MERGER RESERVE 

The merger reserve arose from the difference between the carrying value and the nominal value of the shares of the Company, following completion of the internal reorganisation in 2021.

   15.          PROVISIONS 
 
                                  30 June    30 June  31 December 
                                     2022       2021         2021 
                                Unaudited  Unaudited      Audited 
                                  USD'000    USD'000      USD'000 
 
 
Non-current 
Asset restoration obligations     408,585    286,219      404,400 
Others                              4,866      4,474        6,297 
 
                                  413,451    290,693      410,697 
 
Current 
Others                              3,503      3,091        1,947 
 
                                  416,954    293,784      412,644 
 
   16.          TRADE AND OTHER PAYABLES 
 
                                      30 June     30 June  31 December 
                                         2022        2021         2021 
                                    Unaudited   Unaudited      Audited 
                                      USD'000     USD'000      USD'000 
 
 
Trade payables                          5,602       3,377       26,847 
Other payables                          4,862       1,662        7,627 
Accruals                               33,267      17,714       29,699 
Contingent payment                          -           -        3,000 
Malaysian supplementary payment 
 payables                               2,839           -        1,907 
GST/VAT payables                            5           7           10 
 
                                       46,575      22,760       69,090 
 
   17.          SEGMENT INFORMATION 

Information reported to the Group's Chief Executive Officer (the chief operating decision maker) for the purposes of resource allocation is focused on two reportable/business segments driven by different types of activities within the upstream oil and gas value chain, namely producing assets and secondly development and exploration assets. The geographic focus of the business is on Southeast Asia ("SEA") and Australia.

Revenue and non-current assets information based on the geographical location of assets respectively are as follows:

 
                                  Producing       Exploration/ 
                                    assets         development 
                             Australia    SEA         SEA       Corporate   Total 
                              USD'000    USD'000     USD'000     USD'000    USD'000 
 
Six months ended 30 June 2022 (unaudited) 
Revenue 
 Liquids revenue               175,476    48,256             -          -   223,732 
 Gas revenue                         -     1,907             -          -     1,907 
 
                               175,476    50,163             -          -   225,639 
 
Production cost               (58,792)  (24,609)             -          -  (83,401) 
DD&A                          (33,065)   (1,771)         (117)      (182)  (35,135) 
Administrative staff costs     (7,239)   (2,023)       (1,189)    (4,714)  (15,165) 
Other expenses                 (2,225)     (619)         (663)    (1,996)   (5,503) 
Other income                     5,185        54            14        349     5,602 
Finance costs                  (3,397)   (1,173)         (200)       (14)   (4,784) 
 
Profit/(Loss) before tax        75,943    20,022       (2,155)    (6,557)    87,253 
 
Additions to non- 
 current assets                 12,303       322         2,829         67    15,521 
 
Non-current assets             340,094    58,084        93,650        604   492,432 
 
 
                                   Producing          Exploration/ 
                                     assets            development 
                             Australia       SEA          SEA        Corporate     Total 
                              USD'000      USD'000       USD'000      USD'000     USD'000 
 
Six months ended 30 June 2021 (unaudited) 
Revenue 
 Liquids revenue                138,158           -              -           -     138,158 
 Hedging income                       -           -              -           -           - 
 
                                138,158           -              -           -     138,158 
 
Production costs               (62,492)           -              -           -    (62,492) 
DD&A                           (39,261)           -          (139)       (297)    (39,697) 
Administrative staff 
 costs                          (5,137)           -        (1,397)     (5,533)    (12,067) 
Other expenses                  (8,807)           -          (897)     (2,797)    (12,501) 
Other income                      3,257           -             36         388       3,681 
Finance costs                   (3,907)           -           (26)         (1)     (3,934) 
 
Profit/(Loss) before 
 tax                             21,811           -        (2,423)     (8,240)      11,148 
 
Additions to non- 
 current assets                  14,971           -          2,145         196      17,312 
 
Non-current assets              329,830           -         93,789         842     424,461 
 
Twelve months ended 31 December 2021 (audited) 
Revenue 
 Liquids revenue                293,566      45,644              -           -     339,210 
 Gas revenue                          -         984              -           -         984 
 
                                293,566      46,628              -           -     340,194 
 
Production cost               (182,001)    (24,522)              -           -   (206,523) 
DD&A                           (75,848)     (3,621)          (281)       (465)    (80,215) 
Administrative staff 
 costs                         (13,364)     (1,433)        (1,612)     (8,659)    (25,068) 
Other expenses                 (14,970)     (2,466)        (5,875)     (2,870)    (26,181) 
Other income                      7,038           9             76         559       7,682 
Finance costs                   (7,452)       (875)          (503)       (245)     (9,075) 
Other financial gains                 -           -            266           -         266 
 
Profit/(Loss) before 
 tax                              6,969      13,720        (7,929)    (11,680)       1,080 
 
Additions to non- 
 current assets                  57,130      64,117          4,744         183     126,174 
 
Non-current assets              366,959      59,532         90,938         719     518,148 
 
 

Non-current assets as shown here comprises oil and gas properties, intangible exploration assets, right-of-use assets, other receivables, restricted cash and plant and equipment used in corporate offices. Deferred tax assets are excluded from the segmental note but included in the Group's consolidated statement of financial position.

18. EVENTS AFTER THE REPORTING PERIOD

Acquisition of the interest in North West Shelf oil producing fields

On 28 July 2022, the Group announced the execution of a sale and purchase agreement with BP Developments Australia Pty Ltd to acquire BP's non-operated 16.67% working interest in the Cossack, Wanaea, Lambert and Hermes oil field development, offshore Australia. The total headline consideration is US$20.0 million plus an upfront payment of US$41.0 million into a decommissioning trust fund with two further equal instalments of US$20.5 million into the decommissioning trust fund due on or about 31 December 2022 and 2023, respectively.

The effective date of the transaction is 1 January 2020 and the economic benefits from the effective date until the closing date will be adjusted in the final consideration price. Completion of the transaction is subject to customary closing conditions including various regulatory approvals. The Group anticipates completion of the transaction to occur in Q4 2022.

Launch of the share buyback programme

On 2 August 2022, the Company launched a share buyback programme in accordance with the authority granted by the shareholders at the Company's Annual General Meeting held on 30 June 2022. The maximum pecuniary amount of the programme is US$25.0 million and the programme will not exceed 46,574,528 ordinary shares. There is no certainty on the volume of shares that may be acquired, nor any certainty on the pace and quantum of the acquisitions.

Glossary

 
GBP            British pound sterling 
2C             best estimate contingent resource, being quantities 
                of hydrocarbons which are estimated, on a given 
                date, to be potentially recoverable from known 
                accumulations but which are not currently considered 
                to be commercially recoverable 
AAKBNLP        Abu, Abu Kecil, Bubu, North Lukut, and Penara oilfields 
AIM            Alternative Investment Market 
API            American Petroleum Institute gravity 
bbl            barrel 
bbls/d         barrels per day 
boe            barrels of oil equivalent 
boe/d          barrels of oil equivalent per day 
capex          capital expenditures 
DD&A           depletion, depreciation and amortisation 
EBITDAX        earnings before interest tax, depreciation, amortisation 
                and exploration 
EPS            earnings per share 
FPSO           floating production storage and offloading 
GB pence,      Great Britain pence 
 GBp 
GHG            greenhouse gases 
GST            goods and services tax 
IFRS           International Financial Reporting Standards 
LPG            Liquefied petroleum gas 
LTI            Lost Time Injury 
mm             million 
mscf/d         thousand standard cubic feet per day 
mmscf          million standard cubic feet 
opex           operating expenditures 
PenMal Assets  Peninsular Malaysia Assets 
PITA           Malaysian Petroleum Income Tax 
PRRT           Petroleum Resource Rent Tax 
PSC            production sharing contract 
reserves       hydrocarbon resource that is anticipated to be 
                commercially recovered from known accumulations 
                from a given date forward 
SEA            Southeast Asia 
US$ or USD     United States dollar 
VAT            value-added tax 
 

The technical information contained in this announcement has been prepared in accordance with the June 2018 guidelines endorsed by the Society of Petroleum Engineers, World Petroleum Congress, American Association of Petroleum Geologists and Society of Petroleum Evaluation Engineers Petroleum Resource Management System.

A. Shahbaz Sikandar of Jadestone Energy plc, Group Subsurface Manager with a Masters degree in Petroleum Engineering, and who is a member of the Society of Petroleum Engineers and has worked in the energy industry for more than 25 years, has read and approved the technical disclosure in this regulatory announcement.

The information contained within this announcement is considered to be inside information prior to its release, as defined in Article 7 of the Market Abuse Regulation No. 596/2014 which is part of UK law by virtue of the European Union (Withdrawal) Act 2018, and is disclosed in accordance with the Company's obligations under Article 17 of those Regulations.

This information is provided by RNS, the news service of the London Stock Exchange. RNS is approved by the Financial Conduct Authority to act as a Primary Information Provider in the United Kingdom. Terms and conditions relating to the use and distribution of this information may apply. For further information, please contact rns@lseg.com or visit www.rns.com.

RNS may use your IP address to confirm compliance with the terms and conditions, to analyse how you engage with the information contained in this communication, and to share such analysis on an anonymised basis with others as part of our commercial services. For further information about how RNS and the London Stock Exchange use the personal data you provide us, please see our Privacy Policy.

END

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September 20, 2022 02:00 ET (06:00 GMT)

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