All articles in the Oilpatch Sahara Section:


ION Completes Close to 20,000sq km of 3D Seismic Reprocessing in Mauritania

ION Geophysical Corporation (has completed the reprocessing and reimaging of approximately 19,100 km² of 3D seismic data offshore West Africa for its Mauritania 3D reprocessing programme.

The multi-client project was undertaken through an exclusive agreement with the Ministry of Petroleum, Energy and Mines in Mauritania. It is comprised of 11 vintage seismic surveys and provides a seamless, modern, high resolution data set spanning the Mauritanian offshore coastal basin. This basin is a key part of the frontier MSGBC basin in which several large-scale, offshore, gas fields have been discovered, with an estimated 63trillion cubic feet (Tcf)* in place in Mauritania thus far, ION declares.

“With foreign investment flowing in, field developments expected to come online in 2023, gas favoured as a source of energy for the energy transition, and capacity expected to exceed domestic needs, contracts for LNG export to European and other markets is anticipated”, the company reiterates.

“The MSGBC basin has become one that matters in the global oil and gas landscape, even if it is still today a frontier area. We have an enormous potential and we must find the right solutions to use these resources for the development of the country,” stated Chemsdine Sow Deina, Exploration Director at Societe Mauritanienne des Hydrocarbures (SMH).

“With ION’s delivery of its Mauritania 3D reprocessing program, operators now have a lower cost, lower risk, sustainable solution for evaluating the offshore hydrocarbon potential of Mauritania,” said Chris Usher, President and CEO. “As a result, we anticipate additional discoveries will be made that ensure Mauritania’s long term energy security, as well as exports that fund sustainable economic growth and development.”

The Mauritania 3D reprocessing program was supported by the industry and almost triples the amount of 3D data that ION has delivered this year from approximately 10,000 km2 to 29,000 km2. Final pre-stack depth imaged deliverables are now available. Learn more at iongeo.com/Mauritania.

*Estimate from Mauritania-Senegal: an emerging New African Gas Province – is it still possible? October, 1, 2020. The Oxford Institute for Energy Studies

 


TGS to Start a Second 3D Multi-Client Seismic Survey in the Egyptian Red Sea

The Norwegian geophysical company TGS, has announced a new three dimensional (3D) seismic survey in the Red Sea, Egypt, in partnership with Schlumberger.

This survey represents the second phase of new acquisition for the partners in this region and will encompass a minimum of 5,000 square kilometers. Data will be acquired with long offsets and processed using a Pre-Stack Depth Migration (PSDM) workflow to enable subsalt imaging. The acquisition is expected to start in April 2022, with final products anticipated in mid-2023 to ensure availability ahead of future license rounds in the region.

Egypt’s attractive, stable investment climate, enhanced by established exploration infrastructure and complemented by regular, transparent, and well-managed licensing rounds, has helped bolster interest in the Red Sea. The region is considered to hold significant hydrocarbon potential characterized by a wide range of prospective hydrocarbon systems comprising large, untested structures.

TGS and Schlumberger have a long-term commitment with the Egypt Ministry of Petroleum and South Valley Egyptian Petroleum Holding Company (GANOPE) to promote the prospectivity of the Egyptian Red Sea. Through the acquisition and processing of seismic data. GANOPE is responsible for managing Egypt’s hydrocarbon resource potential under latitude line 28°.

The survey is supported by industry funding.

 


Shell Is Quiet About Rumours of Orange Basin Discovery

Shell has not expressly announced commercial discovery, whether minimal or significant, in its deepwater drilling offshore Namibia.

But everyone has had a say or two about the Graf-1 probe, located in Petroleum Exploration License 39 (PEL 39) in the Orange basin. Upstream, the Norway based oil and gas focused newspaper, had reported a very speculative story of the supposed find.

The well is being drilled by the drillship Valaris DS-10 in 2,000 metres of water.

The global newswire, Reuters, citing “three industry sources”, followed up, insisting the European major had made “a significant oil and gas discovery which could spark a wave of investment in the southern African country”. And then, after using the term “significant”, Reuters goes to state “it is unclear if the discoveries are big enough for Shell to go ahead with the development of the country’s first deep water field”. Reuters’ claim that the Namibian government was planning to make an announcement on the details of the discovery in the week of January 31, 2022, also turned out to be exaggerated.

A noteworthy feature of the speculation is the strong sense of Namibian government push behind it. “Upstream understands from two other sources that senior officials in Namibia’s Ministry of Mines & Energy believe results from the well are “positive” and that “Shell will do well” in the country”, the paper said, adding: “|Last month, just days after information began leaking out about Graff-1’s success, a further source with Namibian connections said Tom Alweendo, Namibia’s Energy Minister, was ‘very excited’ by the results”.

The media has gone so far as to report the density of the fluid (light oil), age of the reservoir (Upper Cretaceous sands, thought to be Cenomanian) and size of the find (a potential 300Million-barrel) It even reports hydrocarbon footage: “one layer at least 60 metres deep of hydrocarbons”.

All of these reports cite Shell executives as unwilling to comment, only grudgingly noting: “We continue to safely execute Graff-1 operations.”


Chariot Makes Significant Gas Discovery Off Morocco

Chariot has announced the presence of “significant gas accumulations in the appraisal and exploration objectives of the Anchois-2 well with a calculated net gas pay totalling more than 100metres, compared to 55metres in the original Anchois-1 discovery well”.

Anchois-2 was drilled on the Anchois field within the Lixus licence offshore Morocco. Chariot has a 75% interest and operatorship of Lixus in partnership with the Office National des Hydrocarbures et des Mines (ONHYM) which holds a 25% interest.

The company says the well, which was spud in late December 2021, has been safely and efficiently drilled to a total measured depth of 2,512m by the Stena Don drilling rig in 381metres of water.

The AIM listed minnow says it undertook a comprehensive evaluation of the well through wireline logging, including petrophysical evaluation, subsurface formation testing including reservoir pressures and gas sampling, sidewall cores and well bore seismic profiles.

Its results are summarised as follows:

Appraisal Target

Gas Sand B has a calculated total net gas pay of more than 50m in two stacked reservoirs of similar thickness. The upper reservoir is a continuation of a reservoir drilled in the original discovery well, Anchois-1, with the lower reservoir being newly identified.

Exploration Targets

Gas Sands C, M & O were successfully encountered with multiple gas-bearing intervals across a gross interval of 250m measured distance with no water-bearing reservoirs identified, materially exceeding pre-drill expectations.

  • Previously discovered Gas Sand A was not targeted in the Anchois-2 well, due to the intention of evaluating it in the subsequent Anchois-1 re-entry operations, however, the Anchois-2 well encountered gas bearing sands at this level providing important additional subsurface data.
  • High quality reservoirs were encountered in all gas sands.
  • Further analysis will be undertaken to fully understand the positive implications on:
        •   Gas resources within the expanded Anchois field and the scale of the potential gas development.
  •   De-risking of numerous additional material exploration prospects within the Lixus licence area with similar seismic attributes to the Anchois discovery now considered to be low risk.
  • The well will now be suspended for potential future re-entry and completion as a production well in the development of the field.
  • The Stena Don rig will then move to the Anchois-1 gas discovery well to perform re-entry operations with the objectives of assessing the integrity of the previously drilled well, and if successful, providing a future potential production well for the development of the field.

 

 


Aggressive TGS Kicks Off Another Seismic Survey in Mauritania

The Norwegian geophysical company, TGS, has announced commencement of a new seismic survey in the MSGBC Basin, offshore Mauritania.

It is a follow up to the North-West Africa Atlantic Margin (NWAAM) two dimensional (2D) seismic acquisition campaign.

The current survey, NWAAM 2021, will comprise 7,500 kilometres of seismic data, with a modern broadband acquisition set-up. The project is being undertaken using the vessel BGP Pioneer

“The survey is designed to illuminate the regional plays in the ultra-deep and deepwater areas with a new azimuth and to provide prospectivity insights of an oil-prone area in relation to recent key wells and the shallow water geology”, TGS says in a release.

TGS has been, perhaps the busiest multi-client seismic survey contractor on the African continent in the last three years. It was the go -to company for the Liberian licensing round, which was launched in 2nd Quarter 2020, because it holds a range of multi-client data across the Harper Basin, the focus of the round, to support the activity.

TGS acquired a keen rival, Spectrum Geophysical, in June 2019 and in 2020 acquired the Senegal North Ultra-Deep offshore three-dimensional (3D) survey, covering an area of more than 5,100km². The stand-alone northern Senegal survey was the continuation of the Jaan 3D seismic survey, which is TGS’ 3D dataset covering the southern portion of the Mauritania, Senegal, Gambia, Guinea Bissau and Guinea Conakry (MSGBC) Basin, offshore north-west Africa.

In Nigeria, between 2019 and 2021, TGS, along with its joint venture partner PetroData, carried out the country’s first regional multi-client Multibeam and Seafloor Sampling (MB&SS) Study, covering an area of approximately 80,000 square kilometres of the offshore Niger Delta and incorporating around 150 cores from the seabed, whose location is based on multibeam backscatter anomalies.

In terms of the ongoing Mauritanian survey, TGS says the project has a 60-day acquisition timeline, with fast-track data available three months after acquisition. The full dataset will be available by Q2 2022.

“Our latest seismic survey offshore Mauritania will provide explorers with the subsurface intelligence needed to assess the hydrocarbon potential of the deep and ultra-deepwater”, TGS says. “We see this project as the natural continuation of our successful NWAAM campaign, one of our flagship projects in Africa”.

 


Chariot Ready for Gas Appraisal Well in Morocco

Chariot Oil & Gas has signed a contract with Stena Drilling, to use its semi-submersible Stena Don drilling rig for the planned Anchois gas appraisal well within the Lixus licence, offshore Morocco.

Drilling operations are anticipated to commence in December 2021 and are expected to take up to approximately 40 days.

 With the drilling, Chariot o wants to unlock the development of the discovered sands by confirming the gas resource volumes, reservoir quality and well productivity.

The probe also seeks to provide a future production well for the development of the field as well as potentially deepen the well into additional low-risk prospective sands with the aim of establishing a larger resource base for longer term growth.

Anchois field’s development plan, so far, envisages two subsea wells tied into a subsea manifold with a 40-km offshore flowline connected to an onshore gas processing facility. From there another 40-km pipeline would link to a trunkline gas system to Europe.

 


Kuwaitis Find New Oil and a Trickle of Gas in Egypt’s Western Desert

Kuwait Energy has flowed a modest crude oil rate and a trickle of gas after drill stem tests were performed on a new field wildcat well in Egypt’s Abu Sennan Concession in the Western Desert Basin.

The company flowed a cumulative maximum rate of 2,834Barrels of Oil Per Day (BOPD and 4.211Million standard cubic feet of gas per day (MMscf/d) on a 64/64″ choke in two reservoirs in the ASD-1Xwell.

For these two reservoirs, the Lower Bahariya and Abu Roash C, the cumulative minimum flow rate was 1,511BOPD and 1.232MMscf/d on a more constrained 32/64″ choke

Modest as these results are, they exceed Kuwait Energy’s pre-drill expectations.

The oil rates are actually higher than the Egyptian average, but the natural gas flow is incredibly small.

Still, the operator has gone ahead to submit an application for a development lease to develop the “field”, within the Abu Senanconcession.

ASD-1X, located 12km to the north-east of the producing Al JahraaField, reached Total Depth (TD) of 3,750m MD on March30, several days ahead of schedule and under-budget.

Apart from the t reservoirs tested, preliminary results suggest the well encountered a combined net pay total of at least 22m across a number of reservoir intervals, including the primary reservoir targets of the AR-C and AR-E, as well as the Lower Bahariya and KharitaFormations.

The well was drilled by the EDC-50 rig, which has now been moved to the Al Jahraa Field, also within the Abu Sennan concession, where the drilling of the AJ-8 development well commenced on May 2, 2021. This well will target the Abu Roash and Bahariyareservoirs in an undrained portion of the Al Jahraa field.

Below are details of the test results:

·    The ASD-1X well tested both the Lower Bahariya and Abu Roash C reservoirs

·    Preliminary short-term test results from the Lower Bahariyareservoir indicate:

o  A maximum flow rate of (c. 2,187bOEPD gross; 481BOEPD net) on a 64/64″ choke

o  A rate of 852BOPD and 1.600MMscf/d (c. 1,172BOEPD gross; 258BOEPD net) on a more constrained 32/64″ choke

·    Preliminary short-term test results from the Abu Roash C (“ARC”) reservoir indicate:

o  A maximum flow rate of 1,215BOPD and 1.371MMscf/d (c. 1,489BOEPD gross; 328BOEPD net) on a 64/64″ choke

o  A rate of 661BOPd and 0.632MMscf/d (c. 787BOEPD gross; 173BOEPD net) on a more constrained 24/64″ choke


Kuwaitis Target A Second Discovery in Abu Sennan

Kuwait Energy Company is moving the ED-50 rig to the north of the Licence, to drill another well, after the moderate success of the last one, which will soon be brought to production.

The next probe is the ASD-1X exploration well, located close to the producing Al Jahraa field. The well is targeting the Abu Roash reservoirs in the Prospect D structure and, if successful, can again be quickly be brought into production.

The last well, ASH-3, a step-out development well in the ASH Field, penetrated a gross hydrocarbon column of 59metres in the primary Alam El Bueib (AEB) reservoir target, 27.5metres of which is estimated to be net pay. The well recorded a maximum flow rate of 6,379 bopd and 6.7 mmscf/d (c. 7,720 boepd gross; 1,700 boepd net), during testing, on a 64/64″ choke, from the AEB reservoir. On a reduced, 30/64″ choke, expected to be more representative of the producing flow rates, the well flowed at 3,561 bopd and 2.9 mmscf/d (c. 4,140 boepd gross; 910 boepd net).

It was spud on the 4th January, and it reached a total depth (TD) of 4,087m MD (3,918m TVDSS) on 8th February.

“The partners, Kuwait Energy and United  Oil and Gas when brought on production over the coming days, ASH-3 will provide a significant boost to the concession-wide production rates that averaged 10,500 boepd gross (2,310 boepd net) during January 2021.

“We look forward to the spudding of the forthcoming exploration well and the remainder of our 2021 work programme,” the partners say.

 


Egypt Launches a Digital “Upstream Gateway”

Egypt’s Ministry of Petroleum says that over 10 international oil companies operating in the country, have signed membership agreement to use the new digital data repository christened Upstream Gateway

In concert with Schlumberger, the oil service giant, the Ministry launched, earlier in the week of February 18, 2021, the “Egypt Upstream Gateway, an innovative national project for the digitalization of subsurface information”.

This digital platform will also enable global access to the country’s subsurface data, “which is kept evergreen by enhancing legacy datasets through reprocessing and new studies”, the Ministry declares. “This unique digital initiative will be used to unlock the potential of Egypt’s petroleum sector and promote the country’s exploration and production potential worldwide”, says Tarek El-Molla, the country’s minister of petroleum and mineral resources.

“The Egypt Upstream Gateway will digitally promote Egypt’s oil and gas bid rounds through seamless online access to the sector’s data, as well as endorsing our exploration potential worldwide.”, Mr. El Molla stresses.

Rajeev Sonthalia, president, Digital & Integration, Schlumberger, explains that “with the launch of this industry-first platform, the Egyptian Ministry of Petroleum and its affiliates—EGPC, EGAS, GANOPE—can digitally showcase national assets to investors worldwide, in addition to leveraging the latest digital technology and solutions to accelerate discovery throughout the country.”

The Egypt Upstream Gateway provides digital access to over 100 years’ worth of accumulated national onshore and offshore seismic, non-seismic, well-log, production, and additional subsurface data under a single platform. This data, which empowers de-risked decisions through the ability to explore multiple basins and evergreen data, can be accessed virtually from anywhere using the platform’s online portal. In addition, the Egypt Upstream Gateway will host Egypt’s upcoming bid round highlighting lease availability information to national and international investors worldwide.

 

 


ENI Discovers Oil and Hooks It Up Quickly in Egypt’s Western Desert

 

By Toyin Akinosho

ENI announced a relatively small new oil discovery in Egypt and hooked it up within a month.

The discovery, in the Meleiha Concession in Egypt’s Western Desert, was achieved through the Arcadia- 9 well, drilled on the Arcadia South structure, which is located 1.5km south of the main Arcadia field already in production.

Arcadia -9 encountered 85 feet of oil column in the Cretaceous sandstones of the Alam El Bueib 3G formation. The well was drilled close to existing production facilities and is already tied-in to production, with a stabilized rate of 5,500 barrels of oil per day.

Following the discovery, two development wells, Arcadia 10 and Arcadia 11, have been drilled back-to-back, the Italian major says in a statement. The first one encountered 25 feet of oil column and the second one 80 feet, within the Alam El Bueib 3G formation. The three wells share the same oil-water contact in the discovered reservoir. Arcadia 11 also encountered 20 feet of oil pay in the overlying Alam El Bueib 3D formation.

“The new discovery adds 10,000 barrels of oil per day to ENI’s gross production in the Western Desert of Egypt”, the company explains.

ENI’s successful implementation of its infrastructure-led exploration strategy in the Western Desert through AGIBA, a joint venture between Eni and Egyptian General Petroleum Corporation (EGPC), allows a quick valorization of these new resources. 

ENI, through its subsidiary IEOC, holds a 38% interest in the Meleiha concession while Lukoil holds a 12% and EGPC a 50% interest.

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