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NNPC’s Announcement of Kolmani 2 Discovery Is Vague on Details

The Nigeria National Petroleum Corporation announced the discovery of hydrocarbons in Kolmani River 2, an appraisal well drilled in Bauchi, in the Upper Benue Trough, Gongola Basin, but was extremely vague on details.

The statement, released by its corporate affairs department, did not state the net or gross hydrocarbon footage in any reservoir(s).

The press release said the well was drilled with “IKENGA RIG 101” to a total depth of 13,701feet, encountering oil and gas in several levels, meaning that hydrocarbon was encountered in several reservoirs more than the only reservoir that encountered gas in the Kolmani 1.

“A Drill Stem Test (DST) is currently on-going to confirm the commercial viability and flow of the Kolmani River reservoirs”, the company said.

The part of the statement that could have passed for a useful status update of the probe was couched in poor professional language:  “On Thursday 10th October, 2019, at 18:02hours, one of the reservoirs was perforated and hydrocarbon started flowing to the well head at 21:20hours in which the gas component was flared to prevent air charge around the Rig”.

What does that mean?

For a well that had been spud as far back as February 2019, a more standard report was expected.

NNPC added that “Preliminary reports indicate that the discovery consists of gas, condensate and light sweet oil of API gravity ranging from 38 to 41 found in stacked siliciclastic cretaceous reservoirs of Yolde, Bima Sandstone and Pre-Bima formations”.

The company said it acquired 435.54km2 of three dimensional (3D) Seismic Data over Kolmani Prospect in the Upper Benue Trough, Gongola Basin. This was to evaluate Shell Nigeria Exploration and Production Company (SNEPCo) Kolmani River 1 Well Discovery of 33 BCF and explore deeper levels.

The Corporation has also acquired additional 1183km2 of 3D seismic data over highly prospective areas of Gongola Basin with a view to evaluating the full hydrocarbon potential of the Basin. NNPC has deployed world class cutting-edge technologies including Surface Geochemistry, Ground Gravity/Magnetic, Stress Field Detection, Full Tensor Gradiometry aerial surveys to de-risk exploration in the frontier basins.

The NNPC plans to drill additional wells for full evaluation of the hydrocarbon volume in the Gongola Basin.


Ghanaian Minnow Spuds Deepwater Well

Ghanaian independent, Springfield E&P,has spud its first well on the West Cape Three Points (WCTP) Block 2 acreage, in the country’s prolific Tano Basin.

The drillship Stena Forth spud Afina-1 at 6.50pm, October 7th, 2019, according to Kevin Okyere, Springfield’s founder and CEO.

Afina-1 is the first of two exploratory wellsthat Springfield proposes to start with on the asset. The second is Oak-1.

Springfield doesn’t say what water depth Afina is located and has also not disclosed the proposed Total Depth. The block itself, WCTP2, lies between 100metre and 1,700metre water depths. Deepwater starts from the 200metreisobath.

WCTP2 was carved out of the West Cape Three Points block, operated by Kosmos Energy, following the delineation of the Jubilee unitisation area. The block was subsequently awarded to Springfield E&P for a seven year exploration period from July 2016.

WCTP2 is situated between the Jubilee field (90,000BOPD) and Sankofa (30,000BOPD) field and is immediately north of Aker Energy’s Pecan, Hickory, Almond, Paradise and Beech discoveries.

The latter extends into the WCTP2 block. The licence consists of two components, an exploration component and an appraisal/development component for the existing discoveries, Odum and Banda.

Springfield operates the block with 82%. The two partners, state hydrocarbon companies GNPC and GNPC Explorco hold 8% and 10% equity respectively. They are both carried.

Springfield has, by merely spudding, achieved history as the first home-grown, African owned E&P operator to spud a well in a new deepwater licence.

Other African owned E&P companies with licences in Ghana include Amni, Oranto, Brittania U and Sahara. They were all awarded their different blocks in the country before Springfield E&P but have not announced any concrete drilling plans.

Africa Oil+Gas Report’s earlier story indicated that Springfield’s first well would be Oak-1. Both prospects are to be tested on the basis of interpretation of an 800 sq kilometre, three dimensional (3D) seismic data, acquired by PGS and paid for by Springfield, in 2017.


BW Gets More than It Bargained For

BW Energy’s side-track appraisal of the Hibiscus Updip oil discovery in Gabon has exceeded the company’s expectations to the extent that it is now expanding the initial hook up plan.

The company’s ‘Phase 3 development plans’ to tie the nearby Ruche and Ruche NE fields back to the Adolo FPSO are now being expanded to include a possible fast-track development of the discovery.

The estimate of gross recoverable oil at Hibiscus Updip, computed from the original wellbore and sidetrack is between 40 and 50Million barrels, according to reports widely shared with the public.

“This successful well enables us to further de-risk Gamba prospectivity in the Hibiscus area where we see significant additional potential”, says Panoro Oil, a minority partner in the asset and the project. “We are extremely pleased with the continued drilling success at Dussafu, and now look forward to the commencement of the production drilling phase at Tortue”.

The DHIMB-1 well was initially drilled in 116 metres of water to a vertical depth of 3,538 metres. On August 30, 2019, an oil discovery was announced in the pre-salt Gamba reservoir with plans to drill a sidetrack to appraise the extent of the Hibiscus Updip discovery.

The well was drilled in the northwest of the structure to test the lateral extent and structural elevation of the Gamba reservoir. The sidetrack was drilled to a Total Depth (TD) of 3,500 metres, (3,049 metres True Vertical Depth Subsea (TVDSS)) approximately 1.1 km from the original wellbore and found a 33 metre oil column with 26 metres of oil pay in the Gamba reservoir with better reservoir character and a similar fluid level to that encountered in the vertical well, DHIBM-1.

Further upside potential exists in the wider Hibiscus area which will be the focus of future exploration drilling.


Accra based Springfield on a Historic Deep-water Journey

By Toyin Akinosho, Publisher

In a matter of weeks, Springfield E&P will be the first home-grown, African owned E&P operator to spud a well in a new deepwater licence.

Its planned drilling of Oak-1, for which it had contracted the Stena Forth drillship, is significant history making.

The 11 year old company plans to follow up the well with another, the Afina-1, both of them in West Cape Three Points (WCTP) Block 2, offshore Ghana.

By all accounts Springfield will be drilling the wells as a full blown operator.

Oak-1 is on trend with the Beech structure, on which Hess Corp. discovered oil in Beech-1 in 2013, in 1,713 metres of water.

Both prospects are to be tested on the basis of interpretation of an 800 sq kilometre, three dimensional (3D) seismic data, acquired by PGS and paid for by Springfield, in 2017.

It will not be the first time that a company owned by African businessmen would drill, or be part of drilling, in deepwater, but there’s a context.

“Other African owned E&P companies with licences in Ghana, including Amni, Oranto, Brittania U and Sahara, were all awarded their different blocks in the country before Springfield.”

The Nigerian founded Erin Energy, now in bankruptcy, was drilling wells in over 400 metres of water offshore western Niger Delta. It was running a 40,000BOPD Floating Production Storage Offshore (FPSO) facility, the Armada Perdana, until it stopped being a going concern in mid-2018. Its licence to OML 120 was revoked by the government in June 2019.

London listed Afren discovered the Ogo field in 2013, said to be one of the largest discoveries in the world in that year, with, in part, funding raised by LEKOIL, the AIM listed firm founded by a Nigerian entrepreneur.

But Erin Energy (formerly Allied Energy, a subsidiary of Camac, and listed in NYSE Amex), was an operator by default; it came from being a non-operating partner to Statoil, which discovered the asset, Oyo field, in 1995, and ENI, which put it on stream in 2010 and was producing it until it pulled out of that asset. At no time from discovery to commissioning was Erin in operational charge of Oyo field.

LEKOIL, meanwhile, was, on Ogo discovery, also a non-operating partner to Afren, a company founded by a diverse mix of nationalities and which also has ceased to exist.

Springfield was awarded the WCTP Block 2 in 2016, with Ghana National Petroleum Corporation (GNPC) and its operating subsidiary, GNPC Explorco, as carried partners.

Other African owned E&P companies with licences in Ghana include Amni, Oranto, Brittania U and Sahara. They were all awarded their different blocks in the country before Springfield but have not announced any concrete drilling plans.

ENI’s New Discovery to Add a Trillion to Nigeria’s Reserves

The new gas discovery by ENI, the Italian explorer, will add a trillion cubic feet (Tcf) to Nigeria’s estimated gas reserves of 200Tcf.

The reservoir was encountered at a previously untested deep level in what is otherwise a brown field; the Obiafu-Obrikom twin structure. In Oil Mining Lease (OML) 61, onshore Niger Delta.

“The well (Obiafu-41 Deep) can deliver in excess of 100Million standard cubic feet/day of gas and 3,000 barrels/day of associated condensates, and will be immediately put on-stream to increase NAOC’s gas production”, the company says.

NAOC, which is acronym for Nigeria Agip Oil Company (NAOC), is one of ENI’s upstream subsidiaries in Nigeria.

Obiafu-Obrikom is the eastern end of the grid line gas pipeline, the Oben-Obiafu-Obrikom (OB3) pipeline, which is under construction by the Nigerian Gas Company. But the immediate market for the newly discovered gas reserves is the Nigeria Liquefied Natural Gas NLNG Train 7 project. ENI also supplies gas to the Okpai Plant, the 450MW power plant it constructed and operates in the Niger Delta region.

ENI is 20% operator, with the state hydrocarbon company NNPC holding 60%, and Oando having 20% in OML 61.

“The well reached a total depth of 4.374 m encountering an important gas and condensate accumulation within the deltaic sequence of Oligocene age comprising more than 130m of high quality hydrocarbon-bearing sands”, ENI says.

The discovery, part of a drilling campaign planned by NAOC JV and aimed at exploring near-field and deep pool opportunities as immediate time to market opportunities, has further potential that will be assessed with the next appraisal campaign.



DPOC Reportedly Hits Mother Lode in South Sudan

By Mbongeni Jolosho, East African Correspondent, in Kampala

South Sudan’s top oil producer, Dar Petroleum Operating Company (DPOC), has reportedly made a discovery in Block 3, in the country’s Upper Nile state.

The news, announced by the African Chamber of Energy (ACE), contains no more details than that the reservoirs encountered may contain 300Million barrels of crude oil recoverable.

DPOC is a consortium of companies, led by the Chinese E&P behemoth CNPC, and including Petronas, Nilepet, Sinopec and Tri-Ocean Energy. The company’s website is not up to date and it doesn’t issue press releases.

DPOC has been the only operator producing oil in the five years since civil war broke out in the country in December 2013. Other companies have resumed production since late last year, riding on the new impetus in the country, bought on by a July 2018 peace accord with Sudan, the northern neighbour (through whose ports South Sudan imports equipment) and the signing of a peace agreement, in early September 2018, which reinstated rebel leader Riek Machar as vice president, formally ending five years of bloody civil war.

The company did announce, at a conference last year, that it had launched a drilling campaign at Paloch, Moleeta, Fal and Gumry fields, in its operated Blocks 3 and 7 with an estimate of 50 wells planned to be drilled in 2019.

ACE’s report of the discovery says that the well, which it did not name, was drilled at a total depth of 1,320 metres near the Adar oilfield in Block 3.

South Sudan had signed earlier this year an exploration and production sharing agreement (EPSA) with South Africa’s Strategic Fuel Fund for Block B2, described by ACE as highly prospective. It is hard to determine how that EPSA would work. The Strategic Fuel Fund is not an E&P company, even though it shares the same parent company, Central Energy Fund, with PetroSA, the South African state hydrocarbon firm.

The ACE report says that South Sudan will be launching a new petroleum licensing round at the upcoming Africa Oil & Power conference in Cape Town on October 9th, 2019

BW Energy Spuds the Hibiscus Off Gabon

Drilling has commenced on the Hibiscus Updip prospect on the Dussafu Marin Permit, offshore Gabon. This exploration well is being drilled with the Borr Norve jackup drilling rig, and is the first well in an intensive six well well campaign planned on Dussafu during 2019b and 2020. The operator is BW Energy.

The Hibiscus Updip well (DHIBM-1) is located about 56 km offshore Gabon in 116m water depth. The well is planned as a vertical well to test the highly productive Gamba and Dentale reservoirs.

The DHIBM-1 well is also located approximately 1.5 km southwest of the Hibiscus well (HIBM-1) drilled by Arco in 1991 based on two dimensional (2D) seismic data, and which found good quality Gamba reservoir with live oil shows. The new well is positioned to intersect the Gamba at what is believed, based on three dimensional (3D) seismic data acquired by Panoro in 2013, to be an updip position from the HIBM-1 well.

Following the DHIBM-1 well, the rig will move on to drill four consecutive horizontal production wells at the Tortue field, followed by an additional exploration well in 2020.

The location of the 2020 exploration well will be based on 3D seismic data that is being currently re-processed with the latest techniques. Based on the results of the processing and exploration wells, a further two additional exploration wells may be drilled once the initial six well campaign has been completed.


Kolmani River Looks Good, NNPC Contracts DST

By Fred Akanni, Editor

The Frontier Exploration Services (FES) Unit of the NNPC, the Nigerian state hydrocarbon company, has awarded contracts to Halliburton to run drill stem tests (DSTs) and tubing conveyed perforation (TCP) on the Kolmani River-2, in Bauchi State, in the Gongola Basin, in the country’s northeast.

In the industry, the application of DST (a tool for measuring reservoir flow rates), is usually an indication that the results of wireline logging have signaled that the well has encountered some commercial pool of hydrocarbon.

The company has kept a tight lid on information, but Africa Oil+Gas Report learns that several feet of natural gas and oil may have been encountered, although the case for commerciality is up in the air.

“The sand is better developed at this location and when we were to hang the 9 5/8 inch casing at some few feet deeper than 10,000feet (3,048metres), we were hardly able to find a shale level to hang”, one source enthused. “We are drilling with a water based mud, so there are no issues about the stability of the well bore”. The story changed in the 8 ½ inch hole, according to our findings. The rate of penetration of the drill bit was so low from 13,100ft to 13, 250ft, according to field report, indicating tighter formation.

Kolmani-River-2 is being drilled to appraise the 1999 gas discovery made by Shell in Kolmani River-1. The Anglo Dutch major drilled the discovery well to a depth of 3,000metres (9,842feet), and Kolmani River-2 is planned to go close to 5,000feet deeper, to 4,350metres (14,270feet) than that, even though the location of the appraisal well is updip of the discovery well.

Shell didn’t test the discovery well, but went ahead and booked 33Billion standard cubic feet of gas as possible estimated recoverable reserves, based on some petrophysical results. NNPC, however, aims to collect as much geosicentific data as possible. “We are taking lots of sidewall cores, lots of fluid samples for PVT. The results are looking good.” The new well is being drilled by the Drillog operated Rig 101.

A commercial sized pool of hydrocarbon in Northern Nigeria will change the entire dynamics of politics in Africa’s largest economy.

ENI Confirms 650MM Barrels off Angola

ENI has continued on its winning streak in Angolan deep-water.

Results of the first appraisal well of the Agogo discovery in Block 15/06, confirm the 650Million barrels of oil in place it had talked about at the end of the discovery well. The company wants to assess further upside that has been indicated in the north of the structure with new appraisal wells.

Agogo-2 encountered 58 metres net of light oil (31° API), in sandstones of Miocene and Oligocene age with excellent petro-physical characteristics. The result confirms the extension of the Agogo reservoir to the north of the discovery well and below the salt diapirs. The well has been planned and drilled as a highly deviated one, to reach the sequences below the salt diapirs and prove the existence of reservoir and oil charge also in this sector of the Agogo megastructure. Data acquired in Agogo-2 indicate a production capacity in excess of 15.000 barrels of oil per day.

Agogo-2 has been drilled by the Poseidon drillship, 3 kilometres north-west of the Agogo-1 discovery well, approximately 180 kilometres from the coast and 23 kilometres from the N’Goma West Hub floating production and storage facility (FPSO). The well was drilled in a water depth of 1,700 metres and reached a total depth of 3,949 metres.

The Block 15/06 JV is composed by ENI, the operator of the asset with a 36.8421% stake, Sonangol P&P which has 36.8421% and SSI Fifteen Limited who holds the remaining 26.3158%. ENI plans to start first production from Agogo before the end of 2019 with a subsea tie back to the N’Goma FPSO. Meanwhile, Eni will continue the appraisal campaign to assess the discovery’s full potential and size its development.


Rystad Sees Rebound in African Frontier Exploration

Norwegian oil and gas consultant Rystad Energy sees a resurgence in ambitious frontier exploration well drilling around Africa, in the next one year.

The continent, it says “appears to be emerging from a long hibernation in terms of oil and gas exploration activities,” and West Africa is the prime locale of these high risk wildcat activities and TOTAL, the French major, will be making most of the probes.

Two such supposedly significant prospects are to be drilled in the Mauritania-Senegal Basin, the flavour of the month for the past five years. “Located on the same structural ridge as the BirAllah and Tortue discoveries, BP’s Orca prospect is estimated to hold gross gas in place resources of 13 trillion cubic feet”, the Rystad statement says, adding  that “TOTAL plans to drill a well on Block C-9 in the Mauritanian basin. This particular well will target a large cretaceous oil and gas play”.

Rystad points to Egypt, where Dana Gas is currently drilling The Merak well a deep-water well in the Mediterranean, scheduled to be drilled to a planned total depth of 2,600 meters, targeting Pliocene turbidite plays along the well route.

Rystad argues that a steep drop in the number of exploration wells in 2015 fueled by budget cuts, failed projects, and poor market conditions has meant that exploration in the region has mostly been on pause and declining further until this year, where an uptick in investments has reversed this negative trend, shining some light on African exploration.

TOTAL’s anticipated first well in Angola’s Block 48, in the ultra-deep-water Lower Congo basin will be targeting a high potential new play in the Miocene and Oligocene channels and lobes. Further down along the southern African coast, the company “aims to drill the deepest well ever completed in the continent”, Rystad reveals. “The Venus prospect is located in a giant basin floor fan of the Orange Basin and is considered to be the largest prospect ever in Namibia”.

The only well that may not be drilled anytime soon is the one credited to a rank unknown company named Trace Atlantic, which  is “currently hunting for a partner to farm out 50% to 70% of its stake” to drill with a frontier deep water floater targeting the Albian age Formosa prospect. Rystad provides neither the geologic basin nor the country location of this Formosa prospect.


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