Regulatory News Archive

Operations Update

24 July 2017

Anglo African Oil & Gas plc, an independent oil and gas developer, is pleased to provide an update on activities with regards to the development of the producing Tilapia oil field ('Tilapia') in the Republic of Congo. 

The Company is solely focused on unlocking the potential of Tilapia, which, in addition to the currently producing horizon of R1/R2, has an undeveloped discovery in the Mengo horizon and exploration potential in the Djeno horizon. Plans have advanced with respect to drilling a new well, TLP 103, which will target production from R1/R2 and the Mengo horizon and will appraise the potential from the Djeno horizon. In addition, the operations team continues work to optimise production from the existing TLP 101 and TLP 102 wells.

TLP 103

Following a detailed evaluation and tender process, the operations team has received all relevant tender submissions and has identified its preferred rig contractor. The Board expects to conclude negotiations with all contractors by mid-August.

AAOG's preferred contractor has confirmed that its rig is available for use by the Company to drill TLP 103 by 30th September following which drilling is expected to take around 45 days.

The rig meets the specification requirements to drill TLP103, and is already located in the Republic of Congo, in close vicinity to Pointe Noire, which reduces mobilisation and demobilisation costs.

Further, after technical evaluation, the Company has decided to use fishbones technology to stimulate and complete the Mengo horizon in TLP103. Fishbones technology uses a large number of small diameter lateral jets or drills from the wellbore to penetrate the reservoir and stimulate production. It is ideally suited to the tight formations that are experienced in the Mengo and is more cost-effective and controllable than the alternative of a one-off conventional frack.

In tandem with the above, the Company remains focussed on optimising production from TLP 101 and TLP 102.

TLP101

Initially, it was considered that the installation of a pump would increase production. After physical inspection of the wellhead, which included stripping the choke well-head, and inspection of the flow lines back to the separator, it was discovered that there were significant amounts of detritus material in the line which could be causing or contributing to the low production. It is also thought that the detritus could extend 300m below the wellhead. The Company therefore decided not to install the pump but instead resolve the issue of detritus material as a means of increasing the flow rate.

Samples of this material were sent to a UK laboratory for analyses, which have proved that the material is 90% organic with a 25%-40% wax content. The Company has determined that the solution for this is to remove as much of the material as possible and then circulate the well, wellhead and flow lines with a toluene solution, under which, in laboratory conditions, the material has reacted and remained in solution. This is an operation which could be completed by the end of August.

TLP 102

As previously announced, the Company re-perforated TLP 102, albeit without achieving production. The well data has confirmed the presence of hydrocarbons and pressure within both of the shallower R1 and R2 horizons. Based on analysis of the data acquired from a pulse neutron neutron log prior to the re-perforation exercise, the Company has determined that the confirmed existence of producible hydrocarbons merits further mechanical intervention to bring this well into production. This further intervention necessitates the use of either the drilling rig used for TLP 103 to re-enter and stimulate the reservoir using fishbones technology or a coiled tubing unit and will therefore take place later this year when equipment is mobilized to drill TLP 103.

Secondary Completion

The Company has concluded all relevant submissions in relation to the completion of the acquisition of the remaining 49% of Petro Kouilou S.A. ('Petro Kouilou'), the owner of a 56% interest in the Tilapia field. As previously announced, the Company has received the consent of Petro Kouilou's partner in Tilapia, Société Nationale des Pétroles du Congo, to this acquisition and importantly, has now also received the consent of the Congolese Ministry of Hydrocarbons. There now remain only a few outstanding technical conditions precedent to Secondary Completion, which the Company expects to be satisfied in the coming days. The Company will make a further announcement in due course.

In the meantime, AAOG enjoys full economic rights over Petro Kouilou by virtue of Initial Completion having occurred and so has the confidence to continue its operations as outlined above.

Corporate

Alongside overseeing the operational work outlined above, since IPO Alex MacDonald, Chief Executive Officer and Oleg Schkoda, Operations Director, have assembled an operational team based in Pointe-Noire. This team has all the technical capabilities for delivering on Tilapia's potential. All members of this team are now in place and the Company has secured the services of highly experienced international and in-country operators. The Company continues to maintain its commitment to maintain tight control over costs and general corporate overheads. The remuneration of the Board and management is tied to ambitious production targets and the team remains confident that these will be met in due course.

David Sefton Executive Chairman of AAOG said, "Notwithstanding short-term delays, we continue to execute the plan as set out in our Admission Document. Phase 1, which involves maximising production from proven horizons via the low-cost workover of two existing wells, is already underway. Analysis of the initial work we have carried out to date on both wells has confirmed the potential to increase production from both TLP 101 and TLP 102 and the operations team has worked hard to refine plans to do so. While doing this, we also continue to pay close and careful attention to both running costs and the cost of drilling to ensure that both remain within budget and that in the case of the former they are kept to a minimum pending an increase in production.

"In tandem with this work, significant planning has taken place on the new multi horizon well TLP 103. As a result of this planning, the team is even more convinced of the potential from Tilapia. In addition to targeting proven reserves in the R1 and R2 sands as well as the Mengo discovery, this well will test the Djeno sands, a highly prolific interval in neighbouring licences. As a result, this new well has the potential to transform AAOG's production and reserves profile and we are looking forward to realising Tilapia's full potential."

This announcement contains inside information for the purposes of Article 7 of Regulation (EU) 596/2014.

 

For further information please visit www.aaog.co or contact:

Anglo African Oil & Gas plc Tel: c/o St Brides Partners
+44 20 7236 1177
David Sefton, Executive Chairman  
Alex MacDonald, Chief Executive  
   
finnCap Ltd (Nominated Adviser and Broker) Tel: +44 20 7220 0500
Christopher Raggett, Giles Rolls, Anthony Adams (Corporate Finance)  
Emily Morris (Corporate Broking)  
   
St Brides Partners (Financial PR) Tel: +44 20 7236 1177
Frank Buhagiar, Olivia Vita  

 

Notes to Editors

Anglo African Oil & Gas (AAOG) is an AIM-listed independent oil and gas company acquiring a 56% stake in the producing Tilapia oil field in the Republic of the Congo. The Company boasts a low-cost production story in a prolific hydrocarbon region with significant exploration upside, differentiating it substantially from its E&P peers. Additionally, management's remuneration is tied to hitting production milestones, reflecting their strong focus on cost control.

Tilapia has an excellent address, being located close to multi-billion-barrel fields that include the ENI-operated Litchendjili field and the 5,000bopd Minsala Marine field. Tilapia currently produces approximately 40.25 bopd from two near-surface intervals. It has an undeveloped discovery in the lower Mengo sands with gross contingent resources of 8.1m barrels and a deeper exploration prospect, with gross prospective resources of 58.4m barrels, in the productive Djeno interval from which the adjacent Minsala field produces.

 

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