Baron Oil Plc, the AIM-quoted oil and gas exploration company with opportunities in SE Asia, Latin America and the UK, is pleased to provide shareholders with the following update on the Chuditch PSC.
Key Points
· Proposal presented to ANPM to allow project to progress
o Includes request for minimum 12-month extension
· Significant upgrade in estimated resources
o Gross Mean GIIP: 4,703 BCF
o Gross Mean Prospective Resources: 3,527 BCF
o Mean Prospective Resources net to Baron interest: 882 BCF
Background
Baron has a 33.33% interest in the shares of SundaGas (Timor-Leste Sahul) Pte. Ltd. ("SundaGas TLS"), the parent company of the Timor-Leste subsidiary holding the Chuditch PSC interest, with the remaining 66.67% being held by a subsidiary of SundaGas Pte. Ltd., a private E&P company based in Singapore. The sole asset of SundaGas TLS is its 100% shareholding in SundaGas Banda Unipessoal Lda., which in turn operates and holds a 75% interest in the PSC, with the remaining 25% carried interest being held by a subsidiary of the Timor-Leste state oil company (Timor Gap, E.P.). Baron therefore has an indirect 25% interest in the Chuditch PSC.
The work programme for the current, initial licence phase of the PSC includes an obligation to reprocess 800 sq. kilometres of 3D and 2,000 kilometres of 2D seismic data in the first two-year period, which expires on 18 December 2021. Thereafter, subject to satisfactory results from the 3D seismic reprocessing, the subsequent commitment is for a well to be drilled in the third and final year of the initial phase of the Chuditch PSC.
Proposal to ANPM
As detailed in the Company's announcement of 11 September 2020, since signing the PSC in November 2019 with Autoridade Nacional do Petróleo e Minerais ("ANPM"), progress has been hampered by unanticipated issues around data access, including access to the critical Kyranis 3D seismic volume recorded in 2012 partly over the Chuditch PSC area. Baron has supported SundaGas TLS throughout this time in its efforts to work constructively with ANPM and others to unlock the situation. As a result, SundaGas TLS has now been able to present a proposal to ANPM which amongst other matters, includes an extension request and which, if accepted, the Board believes will resolve the key issues of access to data, ability to input directly into the re-processing project, and satisfy the Timor-Leste training requirements which are also part of the PSC's work programme.
Extension Request
As a result of the time lost whilst attempting to resolve the data access and other issues referred to above, which have been exacerbated by the COVID-19 situation, SundaGas TLS has requested a minimum 12-month extension to the current, initial licence phase, from the date of grant of such an extension. The additional time is essential in order to complete the agreed work programme, in particular the vital 3D seismic reprocessing, to allow a timely drilling decision to be made.
Update on Technical Evaluation
On 4 February 2020 the Company announced information on the Chuditch PSC, specifically from publicly released reports on the area prepared by Shell Development (Australia) Pty. Ltd. ("Shell") in 1998 and 2001 following the drilling of the Chuditch-1 discovery well. Shell's estimates of volumes of gas initially in place ("GIIP") were limited to the Chuditch-1 discovery and immediately adjacent prospects and parts of prospects lying within the licence area (the ZOCA 91-09 PSC) prevailing at the time. The aggregate gross Mean of those volumes is 2,901 billion standard cubic feet ("BCF") of gas.
Subsequently SundaGas TLS has gathered and interpreted subsurface information, mainly legacy 2D seismic and well data, both regional and specific to prospects lying within the Chuditch PSC, which incorporates areas outside the former ZOCA 91-09 PSC. As a result, the extension of the prospect known by Shell as Bilby, now renamed Chuditch North, is mapped to lie within the Chuditch PSC. The gross Mean volume associated with this extension as estimated by Shell is 258 BCF of GIIP.
Further, a significant new lead has been mapped within the Chuditch PSC which lay in Australian waters prior to the 2018 maritime boundary treaty between Timor-Leste and Australia and was therefore not mapped by Shell or other previous operators in the area. This new lead, named Chuditch North East, is on trend with, and mapped to be in the same reservoir and structural setting, as the Chuditch-1 discovery and the other prospects identified by Shell. This area has more limited legacy 2D seismic data coverage. SundaGas TLS has estimated the Chuditch North East lead to contain a gross Mean GIIP of 1,544 BCF.
The aggregate of these estimated gross Mean volumes within the Chuditch PSC is 4,703 BCF GIIP.
Shell's expectation of gas recovery at the time of their reports was in the range of 55% to 75%. Evaluation studies by SundaGas TLS, incorporating the more than 20 years of technical advances in reservoir management, indicate that the best case expectation of gas recovery is now 75%, which computes to gross Mean recoverable Prospective Resources of 3,527 BCF.
It is noted that the above estimates are not fully compliant with the 2018 SPE PRMS Prospective Resources standard.
Summary of Estimated GIIP and Prospective Resources
The tables below summarise the volumetric estimates, as described above, for the identified discovery, prospects and lead on the Chuditch PSC, on a gross and net attributable basis. The figures represent estimates pending reinterpretation, remapping and volumetric re-estimation, following the planned 3D seismic reprocessing.
As previously reported the geological chance of success ("GCOS") for the Chuditch Discovery was considered by Shell to be 100%; the GCOS for the prospects and lead are subject to ongoing review by the Operator.
Qualified Person's Statement
Pursuant to the requirements of the AIM Rules - Note for Mining and Oil and Gas Companies, the technical information and resource reporting contained in this announcement has been reviewed by Jon Ford BSc, Fellow of the Geological Society, Technical Director of the Company. Mr Ford has more than 39 years' experience as a petroleum geoscientist. He has compiled, read and approved the technical disclosure in this regulatory announcement and indicated where it does not comply with the Society of Petroleum Engineers' standard.
Jon Ford, Technical Director of Baron, commented:
"The results of the technical evaluation of legacy subsurface data have both confirmed and enhanced our view of the hydrocarbon potential in the Chuditch PSC. We look forward to refining the technical case as new information becomes available. Specifically, this will include the results of 3D seismic reprocessing aimed at reducing volumetric uncertainty and increasing confidence in the subsurface image so we may plan future drilling campaigns and commercial exploitation. The new evaluation of the large Chuditch North East lead close to the existing discovery and other prospects further establishes our positive view of this underexplored area."
Andy Yeo, Chief Executive of Baron commented:
"After much work behind the scenes, we are delighted that we have been able to present a considered and workable proposal to ANPM which, if accepted, will allow the project to progress. Meanwhile, a considerable amount of technical work has already been completed which has led to the introduction of a significant new lead - Chuditch North East - which, along with a material upgrade to gas recovery expectation, results in an aggregate gross Mean recoverable prospective resource of greater than 3,500 BCF of gas (more than 580 MMBOE).
