All posts tagged Oil Patch Sub-Sahara


Drilling Starts: Zimbabwe Too Wants to Be an Oil Producer

By Macson Obojemuinmoin

Drilling has started at the first of two potentially play opening exploration wells in Zimbabwe.

Australia based Invictus Energy has spud Mukuyu-1(formerly Muzarabani-1), claiming to target 20Trillion cubic feet + 845Million barrels of conventional gas condensate, which translates to about 4.3Billion barrels of oil equivalent on a gross mean unrisked basis. This makes Mukuyu, in the words of Invictus Energy, “one of the largest oil and gas exploration prospects to be drilled globally in 2022”.

The company says that Baobab-1, the proposed second of the two well campaign, will test “recently identified Basin Margin play”.

The prospects are located in the Cabora Bassa basin onshore Zimbabwe.

The Mukuyu-1 well is designed to target several stacked Triassic and younger sandstones within a 200km2 four-way dip closure on the basement high trend.

Exalo Rig 202 will drill Mukuyu-1 to total depth of 3,500metres

The well will be drilled to a projected depth of 3,500 metres. Drilling and evaluation of the well is prognosed to take approximately 50 to 60 days to complete.

Baobab-1 will take approximately 30 to 40 days to complete. It will target stacked Cretaceous and younger sandstones, within four-way and three-way dip closures, against the southern basin bounding rift fault.

Invitcus says that “Baobab displays similar structural characteristics to the play opening Ngamia discovery in Kenya’s Lokichar Basin, which resulted in subsequent discoveries in the “String of Pearls” along the basin margin”.


Chinese Pick Up Drilling Where Shell Made a Discovery in Deepwater Gabon

China National Offshore Operating Company CNOOC will spud the first of a two well campaign in two blocks divested by Shell in deepwater Gabon.

The campaign is for one well each to be drilled in first quarter 2023 in blocks BC-9 and BCD-10. The latter was where Shell encountered 200 metres of net gas pay while drilling the Leopard-1 wildcat in 2014. Shell was excited by the result at the time and there were speculations (that Shell did not refute), of potential resource of 10Trillion cubic feet of gas in the Leopard structure, which is located below a salt (carbonate) formation.

Shell has since divested from Gabon entirely, with CNOOC Ltd, its partner in the 2014 discovery, taking over 100% and operatorship of both assets in an acquisition finalized in 2019.

For the campaign, CNOOChas inked a contract with rig operator Stena Drilling, for mobile offshore drilling unit (MODU) Stena Icemax. The two (2) well programme has an estimated total campaign duration of 90 days.

The dynamically-positioned dual mast Stena IceMax is a harsh-environment ice-class drillship with managed pressure drilling capabilities.

The drilling programme is crucial to the Gabonese authorities, who have struggled, in vain for the last 30 years, to place Gabon on the deepwater production map of the world. It is the only African oil producing country, lying on the edge of the south Atlantic, without crude oil or gas output from thedeepwater terrain.

 

 

 

 


Shell’s Latest Well on the Bonga Field is a Dud

Bonga -70, the latest well finalised in the ongoing multi-well drilling campaign on the Bonga field by UK major Shell, is a disappointing dry hole.

The probe was an exploration effort, drilled to test a turbidite lobe in the Bonga Main.

The Bonga field has various satellites, including Bonga North, Bonga North West and Bonga South West. The Bonga Main is, as the name implies, the main field. (The Bonga North West, Bonga North and Bonga South West are developed/to be developed, separately).

The Bonga structure has been one of the most durable of the eight deepwater fields that have come on stream in Nigeria since 2003. The field has delivered over 900Million barrels of oil from first production in 2005 to the end of 2021. In that time, the initial field development had been expanded with further drilling of wells in Bonga Main Phases 2 and 3 and through a subsea tie-back that unlocked the Bonga North West in August 2014. The final investment decision has not been taken for Bonga South West.

Bonga field, currently the third highest producing deepwater field in Nigeria is….

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Amni Postpones Obligatory Drilling in Ghana’s Central Tano, Again

Amni Petroleum is still unsure of when it will likely spud its obligatory and widely anticipated first well in   its Central Tano Block, offshore Ghana.

The company is now talking to both ENI and Tullow Oil, to see if it can get a slot in either operator’s drilling campaign.

The Nigerian owned independent was unable to spud its planned first well offshore Ghana in March 2020 because of COVID 19, and it also missed the target to commence drilling in June 2021, as it failed to clinch a slot in Tullow Oil drilling contract with the drillship Ensco-DS4. As of the first quarter 2022, it was looking to utilize a slot in ENI’s three well drilling campaign.

“There’s a clear sight to funding for the drilling”, officials at the Ghana National Petroleum tell Africa Oil+Gas Report, “that has not been the issue” .

But Amni’s inability to drill an obligatory well eight years after winning the asset has put the company on the list of operators who, in the opinion of Ghana’s influential civil society groups, have held on to assets without robust work programmes. “Only seven of the 18 petroleum agreements signed between Ghana and several oil companies, in the last 18 years have performed up to par”, according to the Ghana Petroleum Industry Report, published by C-BOD. “Most of the least performing contracts were signed between 2013 and 2016”, the report says.

The company was awarded the area as the distinct “Central Tano Block” in March 2014 for an initial seven-year term of three exploration phases. Five prospects and eleven leads across the three plays have so far been identified to date with a combined potential of more than 3.5BBO in place, according to Envoi, the London headquartered consultants, commissioned by to assist in its search for a partner

Amni holds 90% of the Central Tano Block in the Tano Basin, with the remaining 10% controlled by the Ghana National Petroleum Company (GNPC), which the company carries.

 

 

 

 


Eco to Spud Gazania-1, off South Africa, in September

Eco (Atlantic) Oil & Gas confirms that the Island Innovator rig, owned by Island Drilling Company AS, has been mobilised and will move on to the Gazania-1 well on Block 2B, 25km offshore the Northern Cape in Orange Basin South Africa.

The rig is expected to arrive and spud by the end of September 2022, subject to weather conditions.

The Gazania-1 prospect is targeting a 300Million barrels light oil resource.

The well will take approximately 25 days to drill, and the JV partners plan to seal and plug the well after the test, with no equipment being left on the sea floor. The partners have also approved the option to drill a sidetrack well contingent on a discovery in the main target.

The JV partnership in respect of Block 2B comprises Eco Atlantic (50% WI and Operator), Africa Energy Corp (27.5% WI), Panoro 2B Limited, a subsidiary of Panoro Energy ASA (12.5% WI), and Crown Energy AB (10% WI).

 


Green Energy: Drilling Campaign Pushes Otakikpo Field Output Close to 10,000BOPD

Completion of the first of a two well campaign has pushed production in Otakikpo field, onshore eastern Nigeria, to slightly above 7,000Barrels of Oil Per Day, Africa Oil+Gas Report has learned.

The field was delivering around 4,000BOPD prior to the campaign, according to the top management of Green Energy International Limited (GEIL), operator of the asset.

“We flowed much more than the 3,000BOPD when we tested the well (Otakikpo-4)”, says Anthony Adegbulugbe, a professor of Energy Management who is the company’s chairman and chief executive officer. “We decided to choke it back (to a lower output) to conserve the energy”, he explains. “Another well is coming that will take us to 10,000BOPD”, the CEO says, referring to Otakikpo 5, the second well in the campaign which is currently drilling.

A 3,000BOPD jump in output from one well in a marginal field is quite exceptional in the onshore Niger Delta in the year 2022, going by the downward trend in production in the region all round.

Two other drilling campaigns on similar fields, carried out elsewhere in the Niger Delta in the last six months, have not been this successful, although those fields have longer production histories than Otakikpo.

Nigeria’s crude oil production slumped from 1.4Million barrels per day in January 2022 to 1.08MMBOPD in July 2022, according to data provided by the Nigerian Upstream Petroleum Regulatory Commission. The numbers are still looking for the floor.

Otakikpo field reached 6,000BOPD, at inauguration in the first quarter of 2017 and has slowly declined in the last five and half years. The ongoing campaign is part of a planned phased development which could take the field to 20,000BOPD. But the existing infrastructure can only accommodate 10,000BOPD

As part of Africa Oil+Gas Report’s C-SUITE Interview series, Professor Adegbulugbe fielded a range of questions on GEIL’s journey as an oil and gas producer, highlighting the phased development of Otakikpo field, the company’s host community engagement, and the plans to be an integrated energy provider with a gas processing plant, a crude oil refining facility, an expanded terminal, and other features of an industrial hub. AOGR will be running the full story on both this online newsletter platform and the monthly e-edition of the report.-Editor.

 

 

 


ENI Pushes its Ivory Coast ‘Oil in Place’ to 2.5Billion Barrels, with Baleine East Discovery

A new discovery offshore Cote d’Ivoire has sharply increased ENI’s oil and gas volumes in place to 2.5Billion Barrels of oil and 3.3Trillion cubic feet (TCF) of associated gas, the company has reported.

Baleine East 1X well, the second find on the Baleine structure, “confirmed the presence of a continuous oil column of about 48metres in reservoir rocks with good properties”, the Italian explorer says in a release. “From the vertical borehole a horizontal drain of 850 metres in length was subsequently drilled into the reservoir to perform a production test that confirmed a potential of potential of at least 12,000barrels of oil per day (12,000BOPD )and 14Million standard cubic feet per day (12 MMscf/d) of associated gas of production”.

The Baleine-1, located in block CI-101 in Côte d’Ivoire, was announced a discovery in September 2021. ENI took an early decision to develop the field and deliver first oil by 2023. Baleine East 1X is located in a water depth of about 1,150 metres, and five kilometres km east of the Baleine 1X, in an adjacent block CI-802. The result has simply extended the Baleine field eastwards.

ENI operates the two blocks with 90% operatorship. The state hydrocarbon company Petroci is a 10% partner.  ENI holds interests in five other blocks in the country’s deepwater, including CI-205, CI-501, CI-504, CI-401 and CI-801, all with the same partner Petroci Holding.

ENI says that its ongoing Baleine Field drilling campaign will continue with the spud of “a third well which will ensure, together with the other two already drilled, the accelerated start-up of production, confirming first oil in the first half of 2023”.

Baleine East 1X well was drilled with the Saipem 12000 drillship. The well reached its final depth of 3,165 metres measured depth.

 


Mozambique Inks Agreement for Multi-Client Seismic Data in Under-explored Basin

Mozambique’s National Petroleum Institute has signed an exclusive agreement with London-based Geopartners to perform a new multiclient, three dimensional (3D) seismic survey over the country’s offshore Angoche Basin.

“The project will comprise acquisition of a minimum 12,000 sq. km of 3D Multi-Client data over Blocks that will be awarded following the closure of the current 6th Licensing Round,” Geopartners says in a release.  “We are honoured to have concluded this new Agreement with INP to acquire this very large 3D seismic survey in the relatively underexplored but highly prospective Angoche Basin”.

The geophysical company says it will apply acquisition and imaging techniques to improve illumination of complex structures to help reduce exploration risk and support potential fast-track production and development. “Pre-acquisition permitting is underway, with the six-month survey due to start early next year”, the release explains. “Early processed results should be issued by year-end 2023”.

Sixteen new licence areas, distributed over four offshore basins are on offer for Mozambique’s ongoing 6th Licencing Round.  The INP has made available 2D and 3D seismic datasets for multi-client licensing, covering 22,700 sq. km of 3D seismic, 41,900 km of offshore 2D seismic and 18,700 km of onshore 2D seismic in the Rovuma, Angoche and Zambezi basins. Geopartners says it is the data release agent for these surveys.

 

 


TOTAL Tackles Decline in Egina Field with New Wells

TOTALEnergies is concerned with the accelerated decline in Egina field, which output around 145,000 Barrels of Oil Per Day BOPD, as of March 2022, a clear 25% plunge from the 200,000BOPD it achieved before the OPEC Quota cut in 2020.

The field is located in 1,500metre water depth in deepwater off Nigeria.

Some of the wells are currently underperforming but about four to five (4-5) well interventions, and two (2) in-infill wells are planned for 2022. The company also wants to examine a satellite play to Egina. The  Egina West (an exploration well) is planned for 2023. If successful, the field will be developed as a tie-back to Egina main.

TOTALEnergies will also re-start the development of the Preowei field, by commencing discussions with the Contractors/Alliances on the modalities for the restart of the FEED CCFT by the second quarter of 2022.

Preowei is a deepwater hydrocarbon pool located north of the Egina field in OML 130. The development is designed as a tie in to the Egina field development, which is delivered as a subsea production system connected to a FPSO (floating production, storage and offloading vessel) designed to hold 2.3Million barrels of oil.

This story was published in the April 2022 edition of the Africa Oil+Gas Report,


PGS Wins “a Number of 4D Seismic Gigs” off West Africa

Norwegian geophysical company PGS says it has been awarded “a significant acquisition contract, consisting of several four-dimensional (4D) seismic surveys, by an international oil company offshore West Africa.

Acquisition is scheduled to start early November 2022 and expected to complete early May 2023.

The contract effectively secures work for the company’s flagship acquisition vessel, Ramform Vanguard until next summer season.

“Combining the Ramform acquisition platform and our GeoStreamer technology will provide the client with high quality 4D data,” says President & CEO in PGS, Rune Olav Pedersen.

 

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