Exploration

The Deepsea Bollsta rig has been released post work completion. (Image source: Springfield E&P)

The Afina discovery offshore Ghana confirmed good reservoir productivity from Cenomanian sandstones, and the presence of gas/condensate from Turonian reservoir

The results followed an appraisal well test activity by re-entry, as reported by Ghanaian company Springfield Exploration and Production Limited and its partners, Ghana National Petroleum Corporation (GNPC) and GNPC EXPLORCO. 

A drill stem test (DST) on the Cenomanian sandstone gave way to a maximum flow rate of 4500 barrels of oil per day confirming good reservoir productivity on the upper end of pre-test expectations, while indicating an estimated flow rate potential of up to 12,000 boepd from a mini-DST conducted on the Turonian sandstone.

Pressure transient analysis from this reservoir showed the pressures consistent with that collected in 2019, when the 1030m-deep Afina-1x was drilled to a total water depth of 4085 metres. 

Northern Ocean Limited-operated Deepsea Bollsta rig that was deployed for the campaign has been released post work completion. 

Considering well completion options

“We are extremely happy with the results of the appraisal programme which has further confirmed our understanding of our geological, geophysical, reservoir models and demonstrated our operational capacity. Afina-1x is a vertical well, we are confident that a horizontal well or other well completion options that maximise reservoir exposure in the fields would deliver much higher production rates. This provides an incredible platform for reaffirming commercial development options for the Cenomanian and Turonian reservoirs," said Kevin Okyere, chief executive officer of Springfield. 

The agreement allows Eni an exploration period of nine years. (Image source: Adobe Stock)

Four new exploration blocks offshore Ivory Coast have been handed over to oil major Eni by the country's Ministry of Mines, Oil and Energy as per an acquisition agreement signed in Abidjan during SIREXE, the International Exhibition of Extractive and Energy Resources 

The agreement allows Eni an exploration period of nine years on the blocks CI-504, CI-526, CI-706 and CI-708. Covering a total area of about 5,720 sq kms with a water depth ranging between 1,000 and 3,500 m, these blocks add to the oil major's already-strong deepwater presence across the region, including in CI-101, CI-205, CI-401, CI-501, CI-801 and CI- 802. Of these, Baleine and Calao remain the company's biggest discoveries at a global scale. 

The partners have been in talks since early this year, when the President of Ivory Coast, Alassane Ouattara, and the CEO of Eni, Claudio Descalzi, met in Abidjan to discuss the company’s activities in the country, including the successful results of the exploration well Murene 1X on the Calao discovery. 

Boosting production 

Eni is increasingly focusing on boosting production from these sites, with the launch of Baleine Phase 2 set for this month, aiming to reach a total production count to 60,000 barrels of oil per day and 70 million cubic feet of associated gas (equivalent to 2 mn cu/m of associated gas). Once achieved, this will mark an increase to 150,000 bopd and 200 mn cu/ft of associated gas during Phase 3, currently under study. 

Interests in Ivory Coast sees growth, as Viridien announced in May two new multi-client 3D reimaging programmes from the region, CDI24 Phase I (3,120 sq km) and Phase II (6,610 sq km).

The results indicated good porosities. (Image source: Adobe Stock)

Light oil and gas-condensate in high quality reservoir-bearing sands revealed itself from the Mopane-1A appraisal well (Well #3) in block PEL83 offshore Namibia as Galp, along with its partners NAMCOR and Custos, cored and logged the well following the end of drilling

The results indicated good porosities, high permeabilities, and high pressures, topped off with low oil viscosity characteristics, involving minimum CO2 and no H2S concentrations. This adds to the AVO-1 quality that also comprises the successful Mopane-1X (Well #1) and Mopane-2X (Well #2) findings. 

Successful appraisal 

“The quality and scale of the Mopane complex continue to be demonstrated with this successful appraisal by the Mopane-1A well. We look forward to the exploration and appraisal activities anticipated in 2025 to further unveil the potential of Mopane,” said Robert Bose, chief executive officer of Sintana.

Data from the appraisal well discoveries will be integrated once thorough analysis is completed. The next steps include E&A wells, and a high-resolution proprietary 3D seismic campaign set to start in December 2024. 

This appraisal well is the first of an up to four-well programme potentially consisting of two exploration wells and two appraisal wells. “The ongoing campaign at PEL 83, with additional wells to come, is part of the next chapter of progress on our world class portfolio at the heart of Namibia’s Orange Basin,” said Knowledge Katti, chairman and chief executive officer of Custos, and a director of Sintana. 

With the Mopane complex alone pointing towards an estimate of more than 10 billion barrels of oil equivalent, the field is considered an important commercial discovery.

The well was drilled to a total vertical depth of approximately 4,030 metres. (Image source: Adobe Stock)

The S-6 (Akeng Deep) exploration well at Block S offshore Equatorial Guinea has been declared a sub-commercial discovery by Panoro Energy and partners, following the completion of drilling and data evaluation 

Drilled to a total vertical depth of approximately 4,030 metres, the well revealed oil zones in the Upper Albian. The drilling was facilitated by the Noble Venturer drillship. 

At Block G, first oil from the Okume infill well was achieved mid-November with production ramp-up ongoing. The Ceiba infill well was brought online by the Block G operator, Trident Energy, mid-October and is performing ahead of expectations.

This marks the end of the 2024 drilling campaign in Equatorial Guinea.

Active petroleum system

John Hamilton, CEO of Panoro, said, "Although the Akeng Deep well did not result in a commercial discovery, the identification of oil in the Upper Albian confirms elements of an active petroleum system and the data provide valuable insights into the potential of the Lower Cretaceous. The well results at S-6 will now be integrated into our subsurface models to refine future exploration and appraisal activities in the basin. At Block G we are pleased to report that both new infill wells at the Ceiba field and Okume Complex are onstream with the Ceiba well performing ahead of expectations and the Okume Complex well ramping up and set to add additional volume.”