Technology

The platform supports critical workflows across Azule’s reservoir and planning functions. (Image source: SLB)

Global technology company SLB has announced a three-year agreement with Azule Energy to extend and enhance the use of its enterprise digital platform across Azule’s operations in Angola

The platform aims to drive more consistent execution, speed up decision-making, and support reliable energy delivery throughout Azule’s portfolio.

Azule Energy, a joint venture between bp and Eni and the largest independent energy producer in Angola, manages some of the country’s most complex assets. This new agreement builds on two years of Delfi use within Azule’s reservoir organization, where the platform supports reservoir studies, modelling, simulation, and well planning workflows, while enabling enterprise-wide digital integration by connecting reservoir workflows with wider operational data environments over time.

“Azule operates large, complex energy assets where execution reliability and consistency matter,” said ND Maduemezia, president, Europe and Africa, SLB.

“This agreement expands the use of an enterprise digital platform that connects workflows and data, strengthening and accelerating decision-making and improving execution predictability in support of reliable energy delivery in Angola.”

The agreement highlights Azule’s shift toward enterprise-scale digital operations, leveraging SLB’s platform and cloud-based capabilities. Implementation is supported through the SLB Luanda Performance Center, which allows digital solutions to be deployed and maintained locally.

The platform supports critical workflows across Azule’s reservoir and planning functions, with gradual integration into broader operational data systems. It also positions Azule to quickly adopt emerging digital and AI-driven technologies, enabling continuous performance enhancements.

Early results demonstrate tangible benefits: integrated workflows, including DrillPlan coherent well planning and engineering solutions, have shortened planning cycles from days to hours while boosting automation and reducing manual coordination.

The enterprise platform strengthens execution consistency across Azule’s large, mature operations, where operational discipline is key to sustaining performance.

Subsea7 will be establishing a single-well tieback. (Image source: Subsea7)

The Aseng Gas Monetisation Project offshore Equatorial Guinea will undergo subsea installation by Subsea7, which has received a significant contract by Noble Energy EG Ltd (a Chevron Company)

Subsea7 will be establishing a single-well tieback for the project, connecting Aseng field to the existing Alen platform. It will transport and install approximately 19 kilometres of rigid production flowline and 20 kilometres of umbilicals, along with associated subsea structures and tie-ins in water depths of 800 metres.

Project management and engineering will commence immediately and will be managed from Subsea7’s Paris office, with additional support from teams in Lisbon and Equatorial Guinea. Offshore activities are expected to begin in 2026.

David Bertin, Senior Vice President for Subsea7’s Global Projects Centre East, said, “This award represents an important milestone in our ongoing global relationship with Chevron. Subsea7 has operated in Equatorial Guinea for nearly two decades, supporting offshore construction and inspection, maintenance and repair activities. We look forward to continuing our collaboration with Chevron on the Aseng Gas Monetisation Project, continuing to deliver safe, high-quality offshore installation services in West Africa.”

New log analysis from latest rock data has refined all previously disclosed results.

With regulatory permits for production testing secured and production liner procured from North America, work crews from Reconnaissance Energy Africa have prepared the Kavango West 1X discovery well in Namibia for testing operations 

Equipment and services will be delivered on site by contracts with Halliburton and SLB, while local suppliers have been engaged in multiple support capacities.

New log analysis from latest rock data has refined all previously disclosed results. The current petrophysical analysis indicates 75 metres (246 feet) of net hydrocarbon pay in the Huttenberg formation, an increase over the previously disclosed 64 metres (210 feet).

ReconAfrica, which is the operator of Kavango West, will be conducting production testing across six optimized zones, three of which are in the Huttenberg formation and three in the deeper Elandshoek formation. A total of 345 metres (1,132 feet) of prospective interval will be isolated and perforated for testing. 

In the shallow waters of Gabon, the company is currently reprocessing 3D seismic data across focused regions for appraisal prospects within the 1,214 sq km-long Ngulu block, including the Loba discovery. 

This strategic block is located on trend to several sizable producing oil fields. The key aspects of the Ngulu block include the Loba oil discovery and over 28 seismically identified prospects in the pre- and post-salt plays. 

The company will be conducting testing and commissioning activities.

Rex-subsidiary, Lime Petroleum Holding AS, has completed hooking up the mobile offshore production unit (MOPU) and the floating storage and offloading unit (FSO) on the Seme Field in Benin

The FSO Kristina has been anchored in place as well. A flow-line has been laid from the Stella Energy 1 MOPU to the FSO. Commissioning of the production system is well underway, with oil now flowing into the FSO. 

This comes as part of 100-day three-well work-programme to redevelop the Seme Field. The campaign will see the drilling of two horizontal production wells in the H6 formation (previously developed), as well as a deeper vertical appraisal well to gather data from the H7 and H8 reservoirs, to facilitate the potential advancement to Phase 2 of the development.

With all connections now in place, the company will be further conducting testing and commissioning activities to attain production optimisation and start regular production. The production start-up and optimisation in the Seme Field will be backed by additional data on the subsurface alongside the existing 3D seismic that has been reprocessed by the team. 

Akrake Petroleum Benin SA holds a 76% interest in the Seme Field in Block 1, Benin, and is the operator. It is a wholly-owned subsidiary of Lime Petroleum Holding AS, an 89.74 per cent subsidiary of Rex.