Oil changed Equatorial Guinea more quickly than almost any other industry could have done. Large offshore discoveries in the 1990s moved the country from a small agricultural economy into the group of African petroleum exporters. Production, export earnings and government revenue rose rapidly as fields such as Zafiro, Ceiba and the Okume Complex came online.
That period of rapid expansion has ended. Equatorial Guinea still holds an important position in the Gulf of Guinea, but its oil sector is now defined by mature fields, declining output and the high cost of replacing production. Proven crude reserves stood at about 1.1 billion barrels at the end of 2025, yet crude production averaged only around 46,000 barrels per day during the year. This was far below the peak of more than 300,000 barrels per day reached in the early 2000s.
The central question is no longer whether Equatorial Guinea has oil. It is whether investment in existing fields and nearby discoveries can slow the decline before export revenue falls further.
Zafiro Created the Oil Economy and Now Shows Its Age
The Zafiro field, located northwest of Bioko Island, was the project that established Equatorial Guinea as a serious oil producer. Discovered by Mobil in 1995, the field began production the following year and eventually produced more than one billion barrels. At its height, Zafiro supported a large share of national output and helped attract international companies to nearby offshore acreage.
Its later difficulties also explain much of the country’s current position. Water entered the Sendje Berge floating production vessel in 2022, forcing the unit to be retired and sharply reducing output from the field. ExxonMobil, which had operated Zafiro for nearly three decades, transferred its remaining interests to the government and left Equatorial Guinea in 2024.
Operatorship passed to the national oil company, GEPetrol. This created a major test for the state-owned company. Zafiro contains known resources and established subsea infrastructure, but bringing more production back requires technical work, capital and a practical redevelopment plan. The field is therefore both an asset and a liability: it offers one of the clearest routes to higher output, but it also carries the cost and operational complexity of an aging deepwater development.
Block G Has Become the Main Center of Active Oil Investment
While Zafiro represents the earlier oil boom, Block G offers a more immediate source of production support. The block contains the Ceiba field and Okume Complex, which are operated by Trident Energy. Six subsea-well clusters and several offshore platforms send production to the Ceiba floating production, storage and offloading vessel.
Recent drilling has shown that mature assets can still respond to targeted investment. Trident completed a deepwater campaign in 2024, and the C-45 well reached a peak rate above 7,000 barrels per day. Infill wells brought online during the same period helped offset natural decline and improved the short-term performance of the block.
The ownership structure also changed in June 2026, when Panoro Energy completed the acquisition of Kosmos Energy’s 40.375% interest. Panoro’s total interest in Block G increased to 54.625%, making it the largest partner, although Trident remained the operator. The transaction placed a greater share of the asset in the hands of a company focused on smaller and mid-sized African producing fields.
This matters because Equatorial Guinea is unlikely to restore production through one giant discovery in the near term. Its more realistic path is a series of smaller measures: infill drilling, workovers, improved facility reliability and low-cost tie-backs to infrastructure that already exists. Block G is well suited to this approach because the production system is already in place and the licenses for Ceiba and Okume have been extended to 2040.
Offshore Infrastructure Gives New Discoveries a Better Chance
Equatorial Guinea’s offshore sector is more valuable than the production figures alone suggest. Several established fields, floating production systems, processing facilities and export routes are located within a relatively compact area. This creates opportunities to develop smaller discoveries that would not justify independent infrastructure.
The country has attempted to build its exploration strategy around this advantage. Acreage close to Ceiba, Okume, Alba, Aseng and Alen may be connected to existing systems if commercial volumes are confirmed. Panoro’s Block EG-23, for example, contains existing oil, gas and condensate discoveries near producing infrastructure. Chevron and GEPetrol have also entered production-sharing contracts covering former ExxonMobil acreage, including deepwater blocks with earlier discoveries.
This infrastructure-led model reduces development costs, but it does not remove exploration risk. Offshore wells remain expensive, and international companies compare Equatorial Guinea with larger opportunities in Guyana, Brazil, Namibia and other emerging basins. The government must therefore offer competitive fiscal terms, reliable contracts and clear approval processes if it wants companies to commit capital.
A reduction in the corporate tax rate for petroleum operations from 35% to 25% from the beginning of 2025 was one effort to improve investment conditions. Licensing rounds and direct negotiations can bring companies into the market, but acreage awards will matter only if they lead to seismic work, drilling and commercially funded development.
Oil Revenue Still Shapes the National Economy
Equatorial Guinea exports most of the oil it produces because its domestic market is small. That export structure once generated very high income per person and financed extensive public construction. It also created deep dependence on a sector whose output naturally declines as fields mature.
The economic effects are now clear. Lower production reduces export receipts, tax revenue and the foreign currency available to the wider economy. It also makes public finances more sensitive to changes in international oil prices. The International Monetary Fund has repeatedly identified declining hydrocarbon production as a major cause of weak growth and fiscal pressure.
Oil activity remains important for service companies, offshore employment, port operations and government revenue, but the industry has limited ability to create broad employment on its own. Deepwater production is capital-intensive and depends heavily on specialist equipment, engineering and international contractors. Greater local participation in maintenance, logistics and technical services could retain more value inside the country, although this requires training, procurement opportunities and predictable project activity.
The decline in oil production also increases the need for economic diversification. Agriculture, fisheries, transport, tourism and regional services are frequently discussed as alternatives, but development outside hydrocarbons has been slow. Oil can still finance diversification, yet falling output means the time and revenue available for that process are becoming more limited.
The Next Phase Will Be a Fight Against Decline
Equatorial Guinea is not returning to the production scale of its early oil boom without a major new discovery. Its immediate objective is more modest: stabilize output, recover value from Zafiro, maintain Block G and connect smaller discoveries to existing offshore facilities.
Success will depend on whether GEPetrol can manage a larger operational role, whether current partners continue drilling and whether new investors see acceptable returns in a mature basin. The country’s 1.1 billion barrels of reported reserves provide a substantial resource base, but reserves do not generate revenue unless projects remain technically reliable and commercially competitive.
The strongest near-term opportunities lie in field redevelopment and infrastructure-led exploration rather than frontier expansion. If those programs are financed and executed well, Equatorial Guinea could extend the life of its oil industry and soften the economic effects of depletion. If investment remains limited, declining production will continue to narrow the role oil can play in the national economy.