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The Great Gambian Hope Did Not Materialise

By Fred Akanni

A frustrating dry hole defines FAR’s first attempt as an operating company

The hope that The Gambia would join the new hydrocarbon rich countries in the North West African margin failed to materialise with the much anticipated well by FAR, the Australian explorer.

Using funds from Petronas, the Malaysian state hydrocarbon firm, FAR drilled its first operated well, Samo-1, offshore The Gambia, to a total depth of 3,240metres.

While admitting that wireline logging had not been completed at the time it went to press with the well results, FAR reports that “interpretation of the wireline logs so far indicates that the main target horizons are water-bearing. Oil shows were encountered at several levels indicating that the area has access to an active hydrocarbon charge system. The well also encountered excellent reservoir and seal facies, indicating that all the key components for a successful trap are present”.

The well operations to date have been conducted safely, efficiently, ahead of schedule and within budget.

FAR had said previously that the Samo-1 well location was picked on the basis of the processing and interpretation of a Multi-Client, Broadband three dimensional (3D) data, acquired by Polarcus in 2015.  The well was drilled in approximately 1,017 m water depth and 112 km  offshore Gambia in the highly prospective Mauritania-SenegalGuinea-Bissau-Conakry (MSGBC) basin. Far had also said it conducted detailed mapping and detailed well engineering of the Samo Prospect, before approving the Samo-1 well location.

Petronas funded 80% of the cost of the Samo-1 well up to a maximum total gross cost of $45Million, under the terms of the farm in agreement agreed to by Petronas and FAR in February 2018. Patronas hd, by then farmed into 40% of the block, reducing FAR ‘s stake to 40%. In addition to the well costs, Petronas agreed to pay FAR cash consideration of $6Million plus 80% of non-well back costs exploration programme.

“As the first offshore well in forty years and the first modern well, the data that has been collected at Samo-1 and the ongoing interpretation will be critical to unlocking the hydrocarbon potential in the area. The well will be plugged and abandoned, consistent with the plan for this exploration well.

The Government of The Gambia confirmed a six-month extension to the current licence to end June 2019 to allow for evaluation of the Samo-1 well results”.


Panoro Looks to Spud Tunisian Well in Mid 2019

Panoro Energy has announced a Heads of Terms agreement with Compagnie Tunisienne de Forage (CTF), the Tunisian state-owned drilling contractor, for the use of the CTF-4, a 2,000-horsepower onshore rig, or equivalent drilling rig, for the drilling of the Salloum West-1 well (SAMW-1) located in the Sfax Offshore Exploration Permit (SOEP). The spud date of the SAMW-1 well is anticipated to be in the first half of 2019 and is subject to the entry into a second renewal period of the SOEP for a period of 3 years, and the subsequent approval of the final drilling program and budget by ETAP. Advanced discussions for the renewal are ongoing with the Tunisian Authorities.

The announcement to spud the SAMW-1 well, to be directionally drilled from the shore as a deviated well, comes only 3 months after the closing of the acquisition of DNO Tunisia AS.

The primary objective of the SAMW-1 well is the Bireno formation, at approximately 3,200 metres vertical depth, where the Company has identified, based on 2D and 3D seismic data, what it believes to be an extension of the Salloum structure to the west. The SAMW-1 well will target an independent fault compartment up-dip from the Salloum-1 well which was drilled by British Gas in 1992 and tested the Bireno formation at a rate of 1,846 bopd.

The objective of the SAMW-1 well is to prove up additional resources in the vicinity of the Salloum-1 well and subsequently fast-track the development of Salloum through a tie-in to existing adjacent oil infrastructure.

The decision to drill this new well is supported by rig availability, cost-savings due to drilling equipment for the well already being owned and stored in Panoro’s Sfax warehouse, existing 2D and 3D seismic covering the SAMW-1 location, close proximity to the Salloum-1 discovery well, the existing adjacent oil infrastructure, and a high chance of success.

The expenditure on SAMW-1 well will be funded from Panoro’s existing financial resources. The well costs will also be an added to the existing substantial cost pool of SOEP which will be fully recoverable against future revenues through crude oil sales.


Zomo-1; Likely Fifth Success or First Duster

Savannah’s Fifth Success or First Duster?

Savannah Petroleum has moved the GW 215 Rig to drill the fifth well in its exploration campaign in the Niger Republic.

Zomo-1, spudded on September 8, follows Bushiya-1, Amdigh-1 Kunama-1 and Eridal-1, all drilled by the British explorer between March and August 2018, and all of which encountered crude oil bearing zones, considered by Savannah to be of commercial size.

But none of the wells have been tested, so there is no clear handle on flow assurance.

As with others, Zomo-1 is located in the R3/R4 PSC Area in the Agadem Basin, south east of the republic of Niger. It is also, as with the rest, designed to evaluate potential oil pay in the Eocene Sokor Alternances as the primary target.

The well is planned to be drilled to a total depth of 2,438metres Drilling is expected to take between 30 and 35 days.

The Company plans to log all prospective sections within the well, with further logging employed for hydrocarbon bearing sections. “In the success case, the well will be suspended for future re-entry and further evaluation, which could include well testing”, the company says.


Savannah Makes The Fourth Oil Discovery in A Row

Savannah Petroleum has announced the fourth consecutive crude oil discovery in the Agadem Rift Basin (ARB) in the Republic of Niger.

 

The Eridal-1 well is the latest reported successful probe in the British operator’s four well campaign, which started with Bushiya-1 and continued with Amdigh-1 and Kunama-1.

 

None of the wells have been tested, so their deliverability is not entirely clear.

 

“Production tests are expected to be performed on at least two of the four wells as a precursor to the Company’s plans to implement our Niger Early Production Scheme (“EPS”)”, the company has explained.

 

All the wells were drilled in the R3 portion of the R3/R4 PSC Area in the ARB, South East Niger.

 

Preliminary results of Eridal-1, based on the interpretation of the available data set (which includes wireline logs, fluid sampling and pressure data) indicate that the well has encountered a total estimated 13.6m of net oil bearing reservoir sandstones in the E1 reservoir unit within the primary Eocene Sokor Alternances objective. Wireline logs indicate the reservoir properties to be good quality and the available data indicates light oil consistent with Savannah’s discoveries to date, and in line with offset wells and the depth/API trend observed across the basin. Oil samples from the E1 reservoir unit have been taken and returned to surface using wireline testing equipment.

 

The well was drilled by the GW 215 Rig to a total measured depth of 2,542m, and encountered the main objective targets at, or near, their prognosed depths. The well took a total of 14 days to reach target depth, and all operations are expected to be completed within 23 days of spud. This compares with a pre-drill expectation of 22 days to reach target depth and 30 – 35 days to complete all drilling operations. No significant geological or drilling hazards were encountered.

 

Eridal-1 is currently being suspended for future re-entry.

 

Testing is expected to require standard production completion equipment to be installed in the wells, enabling them to be connected to the proposed EPS. This well testing programme is currently being planned for later in the year and the Company intends to provide further details in due course. The Company does not expect to provide a discovered resource and volumes report until the well test programme has been completed and evaluated.


SDX Finds “A Lot Of Oil” in Egyptian Appraisal

By Mohammed Jetutu, in Cairo

London listed SDX Energy has made an oil discovery it considers significant at its Rabul 5 Well in the West Gharib Concession in Egypt.
The junior has 50% Working Interest in the concession and is a joint operator.

Rabul-5 encountered 151 feet of net heavy oil pay across the Yusr and Bakr formations, quite a lengthy footage by Egyptian standards. The oil an average porosity of 18%. (With estimated reserves of 2.5Billion barrels, Egypt produces less than 700,000Barrels a day, according to BP’s latest Review of Energy Statistics).

The well was drilled to 5,280 feet total depth. SDX says that further evaluation of the discovery is ongoing, after which the Company expects the well to be completed as a producer and connected to the central processing facilities at Meseda. “Following completion of the Rabul 5 well the Company will move on to the Rabul 4 location, the second of two appraisal wells planned for the Rabul feature in 2018.


SDX Hopes For 150Billion Scuf In New Prospects

By Mohammed Jetutu, in Cairo

Egypt focused junior SDX Energy, is targeting 150Billion standard cubic feet of gas in two new wells proposed to be drilled from mid March 2018.
IbnYunus-1X and Kelvin-1X wells, in the South Disouq concession, will be drilled by the ST-6 rig, owned by the Sino-Tharwa Drilling Company, with which SDX has signed a rig contract for four firm wells and one contingent well.

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Kosmos Hits Three Dry Holes Out Of Four in NW Africa

By Toyin Akinosho
One failed due to charge access, another for lack of trap, the third being evaluated….

Kosmos has encountered another dry hole in its campaign to find oil (and some gas) in the sequences outboard of its gas discoveries in the NW Africa margin.

The prospect, Requin Tigre-1 (Tiger Shark), in Senegal’s Saint Louis Offshore Profond block “was fully tested but did not encounter hydrocarbons”, the company declared on Monday, February 5, 2018.

Requin Tigre-1 was the fourth of a four well drilling programme which featured Yaakar-1, Hipoccampe-1, and Lamantin-1. This particular well was targeted at finding gas, and extending the 15-25Tcf Tortue play.

The well drilled to a total depth of 5,200 meters and was designed to evaluate Cenomanian and Albian reservoirs in a structural-stratigraphic trap, charged from an underlying Neocomian-Valanginian source kitchen. “Post-well analysis is currently ongoing to determine the reasons it was unsuccessful”, Kosmos lamented.

The four prospects are all located in combination strat/structural plays, with Cenomanian-Turonian and Albian oil source kitchen “with increased probability for liquids”.

But Yaakar-1 was the only one that was successful and even then, what it encountered was gas, which wasn’t the primary objective.
Kosmos had encountered tanker loads of natural gas in the Northwest African margin and was hoping to find oil in prospects located outboard of these gas tanks.

Hippocampe-1, drilled in approximately 2,600 meters of water in Block C-8, offshore Mauritania, “encountered well-developed reservoirs in both exploration targets but these proved to be water bearing”. Kosmos’ earth scientists believe that this prospect failed due to a lack of charge access in this part of the play fairway.

Lamantin-1 also came up water wet. Located in Block C-12 offshore Mauritania in approximately 2,200 meters of water, it was drilled to a total depth of 5,150 meters and was designed to evaluate a previously untested Lower Campanian base of slope fan supplied from the Nouakchott River system, trapped in a combination structural-stratigraphic feature, and charged from underlying, oil-prone Cenomanian/Turonian and Albian source rocks. But the Campanian reservoir objective was water bearing with some residual hydrocarbons due to, Kosmos believes, “a lack of trap, related to a combination of up-dip sand pinch-out and top / base seal effectiveness”.

Kosmos, a passionate exploration company, looks on the bright side: “With each exploration well drilled, we deepen our understanding of this newly emerging basin, further refining our geologic model and geophysical tools. Requin Tigre was the last well in our second phase of exploration of the deepwater Cretaceous petroleum systems offshore Mauritania and Senegal targeting large basin floor fan structures.

We have delivered one success (Yakaar) in four wells in this second phase programme, following three successes in three wells (Tortue, Marsouin, Teranga) in the first phase programme targeting inboard structures on the slope. Overall we have discovered gross resource of 40 trillion cubic feet, at a net cost of $0.20 per barrel of oil equivalent benefiting from the partner carry, and have created the potential for two world scale LNG hubs. We will rigorously evaluate our large inventory of prospects across Mauritania and Senegal ahead of the next phase of exploration offshore the two countries.”


SDX Reports A Duster in Morocco

SDX Energy has reported non-commerciality of the ELQ-1 well in Morocco’s Gharb Centre permit.
The well was drilled to a total depth of 1484 meters and has encountered 22.6 net meters of reservoir interval and two meters of marginal net conventional gas pay, in the Hoot formation.

“Management are of the view that the intervals are not sufficiently commercial to complete the well”, the company declares.  “As such, the well will be plugged and abandoned and the drilling rig will move to the ONZ-7 development location”.

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Kosmos Drills Two Dry Holes, Back To Back In NW Africa

Kosmos Energy’s Transform margin experiment is being severely tested. The American junior just plugged and abandoned a second dry hole in deepwater Mauritania, less than three months after the first.
Like Hippocampe-1 before it, the Lamantin-1 well encountered water in the reservoirs prognosed to be oil bearing.

Although Kosmos has proven several gas accumulations, including the large sized Tortue field in the region, the current campaign is to find oil outboard of the gas tanks.

The Lamantin-1 exploration well is located in Block C-12 offshore Mauritania in approximately 2,200 meters of water. Hippocampe-1 was drilled in approximately 2,600 meters of water in Block C-8.

Both were designed to test Lower Cenomanian reservoirs, trapped in a combination structural-stratigraphic feature, and charged from underlying, oil-prone Cenomanian/Turonian and Albian source rocks.

In essence, large, out – board basin floor fan reservoirs trapped primarily stratigraphically, potentially charged vertically with oil / liquids.

Instead, the wells “encountered well-developed reservoirs in both exploration targets but these proved to be water bearing”.

“We are still in the early stages of exploring this newly emerging basin and our forward drilling program remains unchanged given the independent nature of the prospects”, said Andrew G. Inglis, chairman and chief executive officer.

“The drillship will now proceed as planned to test the independent Requin Tigre prospect offshore Senegal, which will be followed by two high-impact oil tests offshore Suriname in mid-2018.”

The Requin Tigre prospect is a Cenomanian/Albian base of slope fan supplied from the proven Senegal River system, and is located approximately 150 kilometres offshore, 60 kilometres west of the Tortue discovery, and 80 kilommetres north of the Yakaar discovery in approximately 3,100 metres of water. It is estimated that drilling will take approximately sixty days.

Kosmos holds rights in the C-6, C-8, C-12, C-13, and C-18 contract areas under production sharing contracts with the Government of Mauritania’s Société Mauritanienne Des Hydrocarbures et de PatrimoineMinier (SMHPM). The blocks range in water depth between 100 and 3,000 meters, and have combined acreage of over 40,000 square kilometers gross. Kosmos is the exploration operator


Kosmos Drills A Duster? That’s Huge

By Sully Manope, General correspondent

This prospect failed due to a lack of charge access

Kosmos Energy, widely regarded as a leading hydrocarbon finder in Africa’s frontier, has come up with a duster off Mauritania, the first in its recent history.

The Hippocampe-1 exploration well is supposed to be one of those probes outboard of the gas discoveries that Kosmos had been making off Mauritania. The search was for oil in as the company’s geoscientists described it: Large, out – board basin floor fan reservoirs trapped primarily stratigraphically, potentially charged vertically with oil / liquids.

Instead, the well “encountered well-developed reservoirs in both exploration targets but these proved to be water bearing”. Hippocampe-1 was drilled in approximately 2,600 meters of water in Block C-8.

Hippocampe-1 was designed to test Lower Cenomanian and Albian reservoirs charged from the deeper Valanginian-Neocomian source, the well was drilled to a total depth of 5,500 meters. The well will now be plugged and abandoned. Kosmos’ geoscientists believe that this prospect failed due to a lack of charge access in this part of the play fairway.

Andrew G. Inglis, Kosmos Energy’s chairman and chief executive officer, said: “Following on from our Yaakar discovery earlier this year, Hippocampe-1 is the second of four tests of independent prospects located in the outboard basin floor fan fairways in our Mauritania and Senegal acreage. Although the well did not encounter oil or gas, it has, together with Yaakar, confirmed the presence of quality cretaceous reservoir in the outboard basin floor fans, which contain multiple leads and prospects, more than 200 kilometers from the north to south through our blocks.

We are still in the early stages of opening this newly emerging basin and our forward drilling program remains unchanged given the independent nature of the prospect tests, in particular with regard to charge.”

The Ensco DS 12 drillship will now proceed as planned to Block C-12 offshore Mauritania to test the independent Lamantin oil prospect. The Lamantin prospect is located approximately 80 kilometers offshore and 180 kilometres northeast of Hippocampe in 2,185 meters of water. The prospect comprises Campanian age reservoirs charged from the shallow, immediately underlying, oil prone, oil mature Albian and Cenomanian-Turonian source rocks.

Kosmos holds rights in the C-6, C-8, C-12, C-13, and C-18 contract areas under production sharing contracts with the Government of Mauritania’s Société Mauritanienne Des Hydrocarbures et de Patrimoine Minier (SMHPM). The blocks range in water depth between 100 and 3,000 meters, and have combined acreage of over 40,000 square kilometres gross. Kosmos is the exploration operator of Block C-8 with 28percent equity and is joined by its partners BP 62% and SMPHM (10%).

© 2018 Festac News Press Ltd..