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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%).


SDX Expects To Finalise KSR-14 in Mid-October

SDX Energy expects to announce the drilling results of KSR-14 in mid-October. The probe is the first of a nine well drilling programme on the Company’s Sebou, Gharb Centre and Lalla Mimouna permits in Morocco.
KSR-14 is a development well and it is located on the Sebou permit.
“On success, the well will be completed, flow tested and connected to the existing infrastructure. These activities are anticipated to be carried out within 30 days of the drilling rig departing the location”, SDX officials say.
The nine well drilling campaign on three permits follows extensive technical work from which the optimal drilling locations were identified, SDX claims. The London headquartered, Toronto and AIM listed explorer is targeting an increase in its local gas sales volumes in Morocco by up to 50% and an increase in its reserves by more than 100% through this drilling campaign.


ENI Is Ready For Its Debut Moroccan Drilling

By Toyin Akinosho

Italian giant ENI has secured the Saipem 12000, a sixth generation ultra-deepwater drillship, for a drilling programme to include a one-well drilling slot in Rabat Deep Offshore in Morocco. It is currently anticipated that the rig will arrive on location in the latter part of Q1 2018 and that the drilling of the RD-1 well on the JP-1 prospect will commence shortly thereafter.

ENI operates the Rabat Deep Offshore licence with 40%. Its partners include Australian Woodside 25%, Morocco’s state hydrocarbon company ONHYM 25%, and the London listed minnow Chariot 10%).

The JP-1 prospect is a large, four-way dip closed structure of approximately 200 square km areal extent, with Jurassic carbonate primary reservoir objectives which, Chariot claims, has an “independently audited gross mean prospective resource estimate of 768MMbbls”.

ENI purchased its 40% on the asset from Chariot, who it is partnering Chariot in return for a capped carry on the drilling of the JP-1 prospect as well as a carry on other geological and administrative costs relating to Rabat Deep Offshore and a recovery of Chariot’s investment prior to farm-out.


Cairn’s SNE North-1 Is Unimpressive, But Better than the Last Probe

By Fred Akanni, Editor

Results of the SNE North-1, Cairn Energy’s most recent probe offshore Senegal, are better than what came out of the FAN South-1 exploration well drilled just slightly earlier.

But the preliminary analysis of the hydrocarbon footage suggests that the reservoirs are not as developed as the equivalent encountered in offset wells SNE 1 and 2.

What is encountered in the primary objective is not oil, but condensate, of 11 metre net thickness. Only four metres of oil was identified in the secondary objective, which had not been probed anywhere else in the sequence and as such could be an upside. “The well encountered oil in the deeper secondary objective, in a separate accumulation to the SNE field”, Cairn says in their release.

The entire gross hydrocarbon interval is however 24 metres thick, which is quite thin compared with 97 metre (average) gross hydrocarbon interval encountered in the same sequence in SNE 1 and 2.

If these are the same reservoirs, as in SNE 1 and SNE 2, then SNE North 1 is not adding any much volume to what’s already documented. If they are not the same reservoirs, however, the fact that they are thinner reservoirs does not preclude them for being better gushers than thicker reservoirs encountered in the offset wells.

SNE North-1 is being plugged and abandoned and the Stena DrillMAX rig will be released.

Cairn is trying to sound optimistic about this result, the second consecutive not-so-great result in the Senegal campaign. “Further work is being undertaken to establish the potential commerciality of this discovery and to integrate the results with the block wide data gathered to date”, the company says. “The well result has positive implications for further hydrocarbon potential to the north of the structural trend containing the SNE field and SNE North-1 discovery well, as well as for broader exploration potential in the permit.

SNE North-1 is located in ~900 metres (m) water depth, ~ 90 kilometres offshore in the Sangomar Deep Offshore block and ~15km north of the SNE-1 discovery. The well reached a Total Depth (TD) of 2,837m. Operations have again been safely and successfully completed ahead of schedule and under budget, following drilling and logging.

“A full set of oil, water and gas samples was recovered to the surface. After completing conventional logging, a series of Modular Formation Dynamic Testing (MDT) mini-fracs were obtained across the reservoir section to help calibrate the geo- mechanical model of the SNE field and aid development well design.

“This marks the end of the five well 2017 drilling campaign”, Cairn says. The operator and its partners are reviewing the potential for further exploration drilling operations in 2018, within the Rufisque, Sangomar and Sangomar Deep Production Sharing Contract area.


SD-1X Flow Rates Exceed Expectations

Operator aims to bring discovery to commercial operation as soon as possible

SDX Energy says the initial well test results of the SD-1X well has exceeded its own expectations as operator.
The well is SDX Energy’s first probe in the South Disouq licence in Egypt where the Company has a 55% Operated working interest.

“SD-1X has successfully flowed dry natural gas at a stabilised rate of 25.8 MMscf/d on a 48/64″ choke”, the company says in a release. “This flow rate exceeded initial expectations and was limited by the surface facilities put in place to test the well”.

The well was drilled to a total depth of 7,777ft, and encountered 82 ft. of net pay with an average porosity of 25% in the Abu-Madi section.

SDX-1 has now been shut in for an initial build-up after which a series of additional flowing periods will be conducted and fluid samples taken. The results from the well testing programme will be integrated into the on-going reserve evaluation work.

The results of that exercise will then be incorporated into an early development plan proposal for discussion with our partners and the authority. This information will be included in a future release to the market over the summer.

Working with its partners, SDX will now aim to bring the discovery into commercial production as soon as possible.

© 2018 Festac News Press Ltd..