Gas

The coming months will see a significant increase in operational activity at Ntorya.

Tanzania is working to build a national infrastructure around the commercial Ntorya gas discovery to boost domestic supply of natural gas

Industrial players in the region, ARA Petroleum Tanzania and Aminex are driving this development as joint venture partners. Following extensive seismic surveys and commercial appraisal, the project is ready for execution. With major financial commitments secured and civil infrastructure nearing completion, work programmes have been initiated to unlock the field's resource potential, strengthen local energy security, and transition from appraisal into commercial production.

Capital outlay and work programme approval

Aminex's subsidiary, Ndovu Resources Limited, and ARA Petroleum Tanzania Limited have approved work programmes for the current and following years, projecting gross expenditure of up to US$75mn during the period.

In Ntorya-2 (NT-2), the joint venture has plans for removal of bridge plugs followed by well testing in November 2026 before production can begin in December 2026. Flowlines will be constructed to activate the Ntorya-Madimba pipeline before production commences. TPDC has confirmed that approximately 95% of pipelaying and infilling work is done. The contract for the supply of the gas processing unit (GPU) is expected to be signed later this month.

Ntorya-1 will undergo wellhead maintenance and slickline operations in October 2026 to determine the next steps, including the prospects of a rig-operated workover. A workover after the drilling of the Ntorya-Central well may affect gas production schedules. 

Negotiations are now at a very advanced stage to contract a drilling rig to drill a well at the NT-C location. The contract is expected to be signed in October 2026 with the well scheduled to be spudded in December 2026 as Ntorya-3 (NT-3). If successful, NT-3 will be tied into the Ntorya development with first gas from the well available in September 2027. 

Potential well appraisals

The results of the NT-3 well will determine if the joint venture wants to use the option available to drill up to two additional appraisal/development wells - NT-E and NT-W - on a back-to-back basis, following the completion of operations on NT-3 and, if required, NT-1. 

An obligatory well called Chikumbi-1 (CH-1) is set to be drilled under the terms of the Development Licence and the Farmout Agreement.

Charles Santos, executive chairman of Aminex, said, "We are pleased to have reached agreement with APT on the revised 2026 work programme and budget and the provisional 2027 programme, which together envisage an expenditure of up to US$75 million across the remainder of 2026 and 2027.

"The coming months will see a significant increase in operational activity at Ntorya, with work commencing at NT-1, testing and first production from NT-2, completion of the pipeline and the planned drilling of NT-3. Importantly, the provisional 2027 programme provides a clear pathway for further early drilling at the NT-E and NT-W locations as we move beyond first production and into the broader development of the Ntorya field.

"We remain focused on maintaining the current momentum and delivering first gas in December."

First gas from NT-1 and NT-2 is targeted for December.

The giant Ntorya gas field development in Tanzania is anticipated to deliver vital domestic energy supplies, alleviate local energy poverty, and drive long-term industrial and economic growth for the country

Tanzanian government authorities have recognised the urgency of the project's advancement and to make sure there is no delay, an optimised timetable has been established in consultation with the joint venture partners involved in the field's development. Designed with an aim to achieve first gas production by December, the packed schedule includes critical well workovers, testing, and accelerated drilling. Fully funded field operations and pipeline infrastructure integration will prepare the site for production generation.

Aminex has reached an agreement on the sequencing and implementation of the Ntorya gas development following a meeting convened by the Tanzanian Ministry of Energy

Key stakeholders convene

Representatives of the Ministry of Energy, the Petroleum Upstream Regulatory Authority (PURA), the Tanzania Petroleum Development Corporation (TPDC), ARA Petroleum Tanzania Limited (APT), the operator of the Ruvuma PSA, and Aminex's wholly owned subsidiary, Ndovu Resources Limited (Ndovu) were present at the meeting.

While the government did not approve the operator's proposal to extend and delay the project timetable, it did confirm a revised implementation schedule with all the parties involved. This schedule comprises workover of the Ntorya-1 well (NT-1) in October, the testing of the Ntorya-2 well (NT-2) in November and the drilling of a newly planned NT-Central well (NT-C) in December.

First gas from NT-1 and NT-2 is targeted for December. Drilling of the Chikumbi-1 well (CH-1) is to proceed after NT-C is drilled. Following the change of management at ARA Petroleum LLC and a technical reappraisal of the Ntorya project, APT had proposed bringing forward NT-C, previously planned as a development well for a later phase of field development, in place of CH-1, with the drilling of CH-1 deferred. The revised implementation schedule plans to drill the NT-C first, followed by the drilling of CH-1.

It was also confirmed at the meeting that the Ntorya to Madimba pipeline will be completed in time to receive first gas from the Ntorya field in December 2026.

APT confirmed to the parties that it had all necessary funds to carry out the revised programme for the development of the Ntorya field.

The parties agreed that APT should execute the planned activities in accordance with the revised implementation schedule and without unnecessary delay. The revised programme will now be progressed through the formal Joint Venture approval process in accordance with the Joint Operating Agreement.

Economic impact of the project

Charles Santos, executive chairman of Aminex, said, "I would like to thank Dr James Mataragio, Permanent Secretary for Petroleum at the Ministry of Energy, for convening the meeting last week and for the constructive approach taken by all parties. Our focus now is on working together to implement the agreed programme and deliver first gas without further delay.

"The revised implementation programme establishes clear near-term operational milestones, targets first gas for December 2026 and provides for the drilling of a newly planned well, NT-Central, while ensuring that the CH-1 well is also drilled.

"Together, these activities form just the beginning of the development of the giant Ntorya field which is expected to deliver large volumes of gas supplies to Tanzanians, helping alleviate energy poverty, boost industrial development and fuel Tanzania's economic growth."

Reservoir properties were above pre-drill estimates.

Following drilling, Vaalco Energy Inc has announced well results on the ETBNM-3 well and has mobilised the rig to a new slot on the SEENT platform to commence drilling operations on the ETSEM-3PH pilot hole and development well

The ETBNM-3 gas-supply well in the crestal portion of the North Tchibala structure from the Dentale D-15 reservoir is now placed for production. Reservoir properties were above pre-drill estimates, with strong porosity and permeability coupled with over 10 meters of net reservoir pay. The well will generate enough gas to cover field operations, liftings and power needs, replacing heavy dependency on high priced diesel. 

The company is still evaluating the potential of the shallower pay intervals encountered in the D-9 and D-12 intervals, and has reported findings that indicate the presence of wet gas to light oil pay.

The ETSEM-3PH, on the other hand, has been planned as a pilot hole and subsequent horizontal Gamba producer near the crest of the central fault block of SE Etame. The pilot well will help to test the original field Oil Water Contact and potential of the underlying Dentale formation.

Following the pilot well, a horizontal development well is planned with a completion length of 300 meters within the Gamba sands.

George Maxwell, Vaalco’s Chief Executive Officer, said, “We continue to execute operationally across our diversified portfolio of assets. In Gabon, the newly successful gas well won’t add production or sales directly but will reduce costs associated with using higher priced diesel; this should improve field uptime and potentially add production uplift to existing wells over time. Our strategy remains unchanged with an ongoing focus on growing production, reserves and value for our shareholders.”

TechnipFMC to support Eni's Baleine project offshore Ivory Coast.

As Eni SpA works to expand production from the Baleine Phase 3 fast track development offshore Ivory Coast, it has signed a significant contract with TechnipFMC to secure its support services

Known as one the largest hydrocarbon discoveries in the region, the fast track development will be supported with a network of flexible flowlines and risers that will be designed and build by TechnipFMC to connect wells in water depths of approximately 1,200 meters to a new floating production unit.

Jonathan Landes, president-subsea for TechnipFMC, said, “This award marks the continued expansion of our collaboration with Eni. We are excited to apply our expertise to provide a robust flexible pipe solution with schedule certainty in support of this fast-track project.”

Previously, TechnipFMC bagged a engineering, procurement, construction, and installation contract offshore Mozambique for the Coral North development in water depths of approximately 2,000 m.

“We are excited to once again work with Eni and their consortium partners in Mozambique. We will leverage our experience gained from the successful delivery of Coral South—the world’s first FLNG project in ultradeep water—by replicating our proven playbook with an enhanced approach,” said Landes. 

The contract will require TechnipFMC to manufacture and install flexible flowlines and risers, alongside subsea manifolds and umbilicals. 

TechnipFMC has secured the contract from the project's operator, Eni, who reached the final investment decision of the Coral North project in October this year, and aims delivery by 2028. 

While Eni is leading the venture with a 50% share, other partners include CNPC (20%), Kogas (10%), ENH (10%) and ADNOC-subsidiary XRG (10%). Eni will be investing on the development of a state-of-the-art floating LNG facility in the Rovuma Basin, where it will be generating gas volumes from the northern part of Area’s 4 Coral gas reservoir. 

The Coral North development follows the success of the Coral South project, which effectively continues to be in production.