Gas

Development work accelerates at Ntorya gas field in Tanzania

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."

Vaalco anticipates substantial gas output from well offshore Gabon

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

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.

Eni, NOC finds gas offshore western Libya

Flow rates were determined from the Metlawi reservoir.

A new gas discovery offshore western Libya has been confirmed by the National Oil Corporation (NOC) and Eni North Africa, following the drilling of the exploration well J1-4/16

After reaching a final depth of 10,458 ft, flow rates across two tests from the Metlawi reservoir stood at 14 million cubic feet per day through a 32/64-inch choke in the first test, and 24 MMcf/d through a 62/64-inch choke in the second.

Lying approximately 95 kilometers from the coast, the well forms part of Contract 4/16, where Eni is the operator, and also remains the final well in fulfilling nine contractual obligations for offshore Contract Block D, as stipulated in the agreement signed in June 2008.

This discovery can potentially add to Libya's production count, which saw an impressive rise last year. According to a table of the average daily crude oil production and total (cumulative) production figures for the past 10 years that was recently released by NOC Libya, 2025 had recorded the highest average production rate in comparison to the last decade, at 1.374 million barrels per day. Total crude oil production for the year reached 501 million barrels, marking a posititve shift in the NOC’s strategy to boost crude oil production rates.

Eni is set to launch three exploration plays in Libya – shallow, deepwater and ultra-deep offshore, and is also deeply invested in the region's gas with the US$10bn Greenstream pipeline and a CO2 capture and storage plant in Mellitah.

Eni finds gas presence offshore Egypt

Eni has discovered gas from the Denise W 1 exploration well.

Following preliminary estimates from drilling activities offshore Eastern Mediterranean, Eni is anticipating the presence of approximately 2 trillion cubic feet of gas initially in place and 130 Mbbl of associated condensates

Discovered from the Denise W 1 exploration well, it especially aligns with the major's near-field and infrastructure-led exploration strategy as it comes with the potential for a massive fast-track development. The well is positioned less than 10 kms away from existing infrastructure, belonging to the Temsah Concession lying 70 km offshore in 95 m of water depth.

As part of substantial investments in brownfield assets, Eni had secured a 20-year renewal of the Temsah Concession in 2025 from the Egyptian General Petroleum Corporation and Egyptian Natural Gas Holding Company. The discovery thus comes as a significant return of investment for the oil major, similar to the now-producing Temsah field, which also featured a gas-bearing sandstone reservoir of excellent quality with about 50 m of net pay like the Denise well.

Eni's joint venture with EGPC, Petrobel, which operates the Denise Development Lease of the Temsah Concession, secures boosted gas output for the country, contributing to its national goals and energy security.

Eni operates the Denise Development Lease of the Temsah Concession with a 50% contractor working interest, alongside bp which holds the remaining 50%.

Eni has been active in Egypt since 1954 and today holds a diversified portfolio spanning exploration, development, and production, with oil and gas production of 242 kboed equity in 2025.