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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.


The State is Aware that Shell Will Sell Nigerian Acreages Upon Renewal

Officials in the Nigerian Ministry of Petroleum Resources are aware that the Anglo Dutch major Shell is inclined to divest from several of the 17 onshore acreages it asked the government to renew.

But they have gone ahead to renew most of the licences anyway, because they think it is unlawful not to do so.  The extant licences on the acreages were due to expire in 2019.

“By the regulations we are working with, all these assets we have renewed deserve to be renewed”, Ministry sources categorically tell Africa Oil+Gas Report.

“Shell can take us to court if we don’t renew”, say ranking government officials in the Ministry, who also argue that, with state sponsored bid rounds not having happened in the country in the last 11 years, the frequent Shell lease divestments since 2008 “have benefited Nigerian companies”, who have purchased the stakes belonging to Shell and other international companies in these assets.

As it is, even during the process of renewal between late 2017 and mid-2018, Shell was actively negotiating on the side, with several parties, its divestment from three of the acreages in the renewal basket: Oil Mining Leases (OMLs) 11, 17 and 25.

Shell was asked to pay $820Million for renewal of 14 of the 17 acreages it sought to renew, including OML 25, an acreage that Shell had put in a divestment round in 2014, but failed to sell because of a last minute NNPC invocation of its right of first refusal. Shell, NNPC and several parties have been involved in closing that transaction since that time.

Regarding OML 11 and 17, Shell has, for a while, been negotiating with buyers and has put a $1.2Billion invoice on the table.

It would seem that such asset should not have been renewed, since Shell had demonstrated that it was going to sell them. It would, ordinarily appear intriguing, that the state would renew the licence of an acreage to a company that had clearly shown it no longer wanted it.

Why don’t you put it in a bid basket so that the state gets the benefit of the licencing?, we asked.

But MoPR officials say that Shell has paid all it needed to pay on every asset in the 30 years since they were last renewed and had extensive work programme on each of the acreages, so it would have been illegal to say no to renewal.

Out of the 17 onshore acreages Shell submitted for renewal in late 2017, only three were revoked, at the provisional conclusion of the process in February 2018, “for lack of enough work done over the last 10 years”.

Shell requested for renewal of OMLs 11, 17, 20, 21, 22, 23, 25, 27, 28, 31, 32, 35, 36, 43, 45, and 46. It succeeded in getting everything renewed, but for four acreages.

OMLs 31, 33 and 36 were denied approval, while the government decided to cut OML 11 into three because it was too large. But Shell has contested the decision on OML 11, arguing that “the proposal would unduly punish” the company, which had conducted operations in the asset “legally and in full compliance with the law”.


Angola Needs to Drill More Oil Wells to Produce Gas

By Sully Manope, in Soyo

Angola’s LNG plant has dropped in production as a result of reduced amount of natural gas that come from the crude oil platforms that supply it.

It sounds intriguing, but the plant relies entirely on associated gas: natural gas which cohabits in the same reservoirs as crude oil.

ALNG’s production capacity is 5.2 Million Tonnes Per Annum (5.2MMTPA). The train can process up to 1.1 billion cubic feet of natural gas per day,

Diamantino Azevedo, Angolan Minister of Mineral Resources and Oil is quoted by Angolan state news agency Angop, as saying that additional investments are needed in drilling more oil wells in the country, in order to increase the natural gas that is channelled to ALNG plant “to reach the installed production capacity.” The minister reportedly added: “This is a challenge that Angola LNG and the country have to take on, in order to achieve capacity and maintain project stability over a long period of time”.

The immediate challenge to Mr. Azevedo’s wish is the immediate status of Angolan rig count. Angolan rig activity figures had crashed from robust 22 in September 2015 to 4 in August 2018, according to the August /September 2018 edition of the monthly Africa Oil+Gas Report.

Angolan LNG has had its fair share of challenges since it came on line in 2013. Barely a year after commissioning, it faced an extended plant shutdown of more than two years from April 2014 to June 2016 to fix a number of design issues that caused an incident on 10 April 2014

That situation led Chevron, the operator, to create an internal project management system to better track contractors and subcontractors on major projects. Chevron is the largest stakeholder in the facility, holding a 36.4% interest, with partners that include Sonangol, 22.8%, and BP,  ENI and TOTAL, with 13.6% each.

 


Shell Plots A Return To Angola

By Moses Aremu, Editor

Anglo Dutch major Shell is keen on purchasing the operator stake in Angola’s Blocks 21/09 and 20/11, two very prospective acreages in the deepwater Kwanza Basin. These are the assets that Cobalt Energy, the US minnow, operated in the country until 2015, when it sought to sell its 40% stake in them to Sonangol, the state hydrocarbon company, for $1.75Billion.

That transaction fell apart in 2016, and Cobalt took Sonangol to international arbitration over its failure to extend the licence deadlines. The two companies reached a settlement-Sonangol reported in December 2017- which called for Sonangol paying $150Million by February 23, 2018 and a further $350Million by July 1, 2018.  

Sonangol has now put up, for auction, Cobalt’s 40% stake and operatorship of these assets.

Observers see Shell’s interest in the blocks as a way of re-entering the country. Cobalt’s 2016 annual report indicated that it made seven discoveries in the blocks with a total of 750Million gross barrels of oil equivalent. A significant part of the volume is natural gas, the hydrocarbon fluid type that Shell is most interested in trading with.

Shell went to Sonangol’s data showroom in Houston on early June 2018, with a delegation of about a dozen officials and the company was widely speculated as the leading contender for the assets.

Shell was one of the earliest entrants into the deepwater activity in Angola between the early and late 1990s. Its Bengo-1 well, drilled in Block 16, tested 1,780BOPD in one reservoir, the first discovery in deepwater Angola. The company’s initial enthusiasm about the structure was restrained by the well’s high gas cap and pancake thin reservoirs, but Shell was willing to risk an early production. The enthusiasm waned when Bengo-2 turned out to miss even the thin bed that was of such fascinating interest in Bengo-1. Then the more it drilled, the less fortunate the company got.  Whereas other operators: TOTAL, Chevron, ExxonMobil, even BP, went on to make discovery after giant discovery, Shell got trapped in a run of ill luck, drilling nine wells in Block 16, most with marginal results. This is curious, because Block 16 is located between the two most successful leases in the country: ExxonMobil’s Block 15 to the north and TOTAL’s Block 17 to the south. The last well Shell drilled in Block 16 was Chiluango-1 which was abandoned in early November 1998 as a dry well. In 1999, the company packed out of Angola and shifted its gaze to Nigeria where, by 1996, it had become sure of the deliverability of its huge Bonga structure, located in the upper slope of the deepwater Niger Delta.


Mixed Grill in The Indies’ Camp

By Fred Akanni, Editor in Chief

Africa focused Western independents, listed in London, Toronto, Oslo and New York, have a mixture of experiences about projects they are pursuing on the continent.

While it’s true that the depressed crude oil price period of 2014 to 2017 hit them hard, and several of them were on the retreat from Africa, the overall investment narrative about this species is a lot more comprehensive.

For every Ophir Energy (who is harassed by government, spurned by partners and cold shouldered by financiers), there is a Kosmos Energy, (who is applauded by the market and hailed by government partners).

For every Tullow Oil that is counting both cost and listing its blessings to look on the bright side, there is an Africa Oil Corp. which is collecting a Landlord’s rent and is on an acquisition binge.

One challenge that is common to most independents is that the new oil and gas reserves that were discovered in the heyday of the last boom have now reached development phase.

Our question remains: Are these independents still, as a group, the markers to where the opportunities lie in Africa?

Africa Oil+Gas Report’s 2018 edition of Independents’ Day, the magazine’s once-a -year review of activities of foreign independent companies operating in Africa, pays close attention to the results of these companies’ exploration ventures in little known basins on the continent, as well as details of plans for the near term. Our job is much more than presenting the general picture. It is to ensure that wherever you are on the planet, you get such a grasp of deal flow, operational plans, and short to mid-term strategies that provide you enough understanding of what’s going on around Africa’s hydrocarbon resources to make a profitable investment.

The Africa Oil+Gas Report -a monthly trade journal-is the primer of the hydrocarbon industry on the continent.

Find out in these pages.

 


Sinopec Pays $3.1 Billion For A Chunk Of Egypt

Pompey's Pillar in Alexandria..Photo by Toyin Akinosho

Chinese behemoth Sinopec is paying $3.1 billion for 33 percent of  Apache Corp’s hydrocarbon assets in Egypt. The two companies say that this is the first step of a global strategic partnership to pursue joint upstream oil and gas projects. Apache will receive the money in cash, subject to customary closing adjustments, in exchange for Sinopec gaining a 33 percent minority participation in Apache’s Egypt oil and gas business. Apache will continue to operate its Egypt upstream oil and gas business.

The Egypt partnership is subject to customary governmental approvals and is expected to close during the fourth quarter, with an effective date of January 1, 2013.

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MODEC Wins FPSO contracts for TEN Project in Ghana’s Deepwater

Japanese contractor MODEC has won the contracts for the supply, charter and lease, operations and maintenance of a Floating Production, Storage and Offloading (“FPSO”) vessel for the Tweneboa, Enyenra, and Ntomme (“TEN”) fields in the Deepwater Tano contract area in water depth averaging 1,500m.
The contracts were awarded to TEN Ghana MV25 B.V., a subsidiary of MODEC, by Tullow Ghana Limited, a wholly owned subsidiary of Tullow Oil plc, Modec said in a statement. Deepwater Tano contract area is held by Tullow (47.175%) as Operator, Kosmos Energy (17%), Anadarko Petroleum (17%), Sabre Oil & Gas Holdings Ltd, a wholly owned subsidiary of Petro SA (3.825%), and the Ghana National Petroleum Corporation (15%).
“MODEC is responsible for the engineering, procurement, construction, mobilization and operation of the FPSO, including topsides processing equipment as well as hull and marine systems. SOFEC will design and provide the mooring system”, the statement said. “MODEC will convert the VLCC Centennial J into an FPSO. The FPSO will be capable of handling expected plateau production of 80,000 barrels of oil per day, 170 MM standard cubic feet of gas per day and has storage of 1,700,000 barrels of total fluids”.
Scheduled for delivery during 2016, the FPSO will be installed in the TEN field and is designed to remain operational in the field for up to 20 years. This is the second vessel MODEC will provide and operate in Ghana following the FPSO Kwame Nkrumah MV21 for the Jubilee Field development, which was awarded in 2008. MODEC is currently operating the FPSO Kwame Nkrumah MV21 for Tullow as Operator of the Jubilee Field.
Toshiro Miyazaki, President and CEO of MODEC said, “MODEC is very proud to have been selected by the TEN field partners and GNPC to provide and operate the FPSO for TEN, a world class facility in a world class field. We are equally pleased to be a part of the team that will provide a needed energy resource for the benefit of the people of the Republic of Ghana.”
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Chevron Suffers Another Rig Mishap Off West Africa

By Njoroge Ahmad, in Luanda

Chevron Corp. has, for the second time in 20 months, experienced a rig accident in a shallow water operation off the coast of West Africa.

Perro Negro 6, a Saipemowned rig working for the San Ramon based major, sank offshore Angola on the night of July1, 2013, after the seabed collapsed under one of the rig’s three legs. The rig was being positioned for drilling operations near the mouth of the Congo River, before it sank.web

Perro Negro 6 is a self elevating drilling platform. A relatively new facility, it was built by Labroy Shipyard in Batam, Indonesia and commissioned in 2009. The rig was under contract with Chevron Corp. through early 2015.

The Angolan incident comes in the space of one year and six months after a Jack up rig operated by a local contractor caught fire offshore Nigeria. In mid January 2012, a fire ignited aboard the K.S. Endeavor, a drilling rig offshore operated by FODE Drilling Nigeria Limited. The rig was drilling a natural gas exploration well, located in Chevron’s Funiwa Field, 10 kilometers offshore and in approximately 12 meters of water. The fire finally went out on March 2, 2012, a month and half later, as the well bridged over and plugged itself, thereby shutting off the flow of natural gas that had been feeding the fire. Chevron, however finalized a relief well so that the failed Funiwa-1A well could be properly plugged and abandoned.

Saipem, which released the statement on the Perro Negro disaster, said that the rig had no personnel on board at the time it capsized and sank at around 10:30am local time, on July 1, 2013. The rig-owner added that one person was missing and six sustained minor injuries. “After the sudden and significant tilting, among the 103 crew members, one was recorded missing and another six incurred minor injuries,” Saipem said. “At this moment, no environmental impacts have been reported, and all the prevention measures are being implemented.”


Tullow Walks A Tight Rope

The Irish wildcatter negotiates a balancing act between headline grabbing exploration successes and field development risks

“Tullow needs a high profile exploration success to reset sentiment”, writes Investec Securities, the financial analysts.

The company is challenging Tullow Oil’s carefully constructed image of the lead game hunter in the African frontier, asking stockholders to sell the explorer’s shares. “While still a best-in-class explorer”, says the UK based Investec, Tullow “has grown increasingly leveraged to the “P” rather than the “E” side of its portfolio”.

Tullow annua web

Tullow engages a community in Uganda: getting to production here has been a long, hard slog

 

Tullowreported worldwide working interest production of 79,200 BOEPD in 2012, of which 57,850BOEPD, or 73%, came from African oil and gas fields. These compare with 78,000BOEPD worldwide working interest production in 2011, of which the African output was 53,000BOEPD.

The London listed independent is getting stuck in the exploration wilderness, spending money on vast tracts of underexplored basins even as its production flattens out. Uganda is not coming on stream as quickly as the company hoped as far back as 24 months ago; Ghana hasn’t reached peak production that was promised at on-stream date in December 2010.The company is the operator of the flagship oilfield project in Ghana and the main player in the upcoming production in Uganda. Still, Investec’s views do not necessarily jell with everyone else’s opinion. “Three research analysts have rated the stock with a sell rating, six have assigned a hold rating and twelve have assigned a buy rating to the company. Tullow Oil has a consensus rating of Hold”, the Mideast Times reported on April 30, 2013.

On the bright side,Tullow Oil made the first commercial find in Kenya in 2012, has a long list of exploration and appraisal wells in East Africa, holds the largest acreages under licence in Mauritania, and has participated in the promising Sierra Leone-Liberian basin. The Ghanaian government has given approval for the Plan of Development of the Tweneboa-Enyenra-Ntomme“TEN” cluster of fields, which is now expected to deliver first oil in 2016, with a plateau production rate of 80,000 barrels of oil per day. Future development of gas resources at TEN is anticipated following the commencement of oil startup.  In Kenya, Tullow tested 2,312BOPD in three levels in Twiga South-1, the second discovery in the country. In Uganda, the uncertainty over the size of the refinery to accompany the 200,000BOPD developmenthas been cleared, with President Museveni agreeing to Tullow’s suggestion of  30,000BOPD refinery, alongside the export of crude.

But the exploration successes are mixed and, in the view of Investec, do not provide enough assurance for the market in the face of its sluggish upward movement in hydrocarbon output which provides the hard cash.The two other wells drilled in Kenya and Ethiopia (Paipai-1 and Sabisa_1)haven’t delivered clearly successful results. Ivory Coast keeps coming up with disappointing results and Tullow’s work in the Equatorial segment of South American basins, particularly in French Guiana haven’t been a commercial success.

Investec  highlights “a production profile that has slipped materially to the right, a looming capex bill and an exploration portfolio that, while strong, may not have enough depth to offset fresh production disappointments that Tullow”. The financial analysts say they “estimate a current capex bill (dependent on disposals) in excess of $18Billion out to 2020. As a result, progress on disposals at TEN field and possibly Uganda is required to help meet its capex commitments which can’t be funded by internal cashflow”.

While Tullow and partners are cheering the Ghanaian Government’s approval of TEN, Investec reminds everyone that the 2016 first oil date simply means that the2ndHalf 2015-for-first-oil worst case scenario, suggested in late 2012, has even slipped.

Tullow insists its strength is more about its ability to pick the right exploration targets. “Our exploration-led growth is enabled by our financial strength, which has been significantly enhanced over recent years”, says CEO Aidan Heavey. “We have increased our operational cash flow from production and while we are not a production-driven business per se, it is a key component of the cash flow required to finance a major exploration programme”. Heavey explains that portfolio management is another rich source of funding opportunity for the business. “As part of our ongoing activity, we will sell or reduce our interest in assets at different points in the value curve to either increase the rate of return on investment from our portfolio or to use the proceeds to recycle cash and maintain capital efficiency”.

To which Investec responds that the portfolio management is not robust. While progress may have been made onthe decision regarding the size of the Ugandan refinery, there still had not been a government approval for the field development, as of June 12, 2013 and this reinforces misgivings about first oil date. “The 2016 first oil target is slipping to a broader 2017-2018 range”, Investec says, arguing that it sees “delays over pipeline routes as a key risk”.

Even if Tullow completes the sale of its Asian assets and Southern North Sea assets in 2013(contributing ~23,000BOEPD), Tullow would still be very challenged.Investec also thinks thatTullow’s admission that the remaining resources to southeast of Jubilee in West Cape Three Points (WCTP) are unlikely to be developed as a standalone project but instead be brought back through the Jubilee FPSO, adds to the odds stacked against Tullow.

Some analysts “advise” Tullow Oil, with a market cap of $16.5Billion, to “emulate the model of Afren”, a much smaller (market cap $2.12Billion), London based producer. Afren acquires undeveloped discoveries, mainly in Nigeria for the purpose of speedy production, and then ensures there are exploration property in its portfolio, in places like Ghana and East Africa, largely for strategic purposes. The key difference is that whereas Tullow lines up assets for both exploratory and development activities, Afren focuses almost entirely, on field development.

There is fundamental irony here. Tullow grew into reckoning largely by acquiring producing, or ready-to-be-produced, assets. Its takeover of Energy Africa in 2004 (the signal event in its 28 year history)doubledTullow’s size by giving it ownership of producing fields in Equatorial Guinea, Gabon and Congo Brazzaville. Now that it has moved further upstream to grow some property organically, it is struggling with the balance.

Investec declares that Tullow may not meaningfully maintain production above 100,000BOEPD until 2018. The analyst sees delays across the company’s production portfolio will put upward pressure on Tullow’s net debt

Tullow argues that financial results in line with market expectations and balance sheet substantially strengthened through debt re-financing and $2.9bn from Uganda farm-down. But the company itself admitted, in the Half year 2012 report, that the Net Income that wasup by 63%, due to the farm down, was “offset by increased exploration write-offs”

Incidentally, Exploration successes-even when field development may be quite far way- are as crucial for Tullow Oil as rapid increase in the production profile. “2012 showed just how much Tullow has to do to keep pace with the exploration expectations the market sets for it”.

In other words, Tullow’s challenge is a result of its own success.”Tullow remains the benchmark for London listed explorers in terms of success ratio and its approach to exploration”, Investec says. “Our view is that the market already appreciates this and as a result, Tullow must deliver exceptional Exploration and Appraisal(E&A) results consistently in order to meet the elevated expectations it is set”.

 

 


Who Is Drilling What And Where In 2013?

KOSMOS IN GHANA

Kosmos Energy’s Offices In Accra, Ghana

Herewith, a rough, intelligible schedule of exploration and appraisal wells in Africa’s Frontier Basins in 2013.. Overlap from 2012: The Sapele-1 exploration well on the Deepwater Tano Block off Ghana was spud in December 2012. The well is targeting multiple Turonian-aged reservoirs, below a water depth of approximately 1,840 meters. Drilling had reached a depth of approximately 3,900 meters as of the time of our going to press. The primary target encountered a high-quality water-bearing reservoir. Drilling operations at Sapele-1 are continuing to additional reservoir intervals, with total depth for the well planned to be approximately 4,100 meters. The well is expected to reach its total depth in the first quarter of 2013.

Paipai-1 in Kenya had been suspended after  a total depth of 4,255 metres as of the time of our going to press in late February, 2013. Light hydrocarbon shows were encountered while drilling through Lower Cretaceous sands but they couldn’t be flowed.
African Petroleum made a discovery in the Bee Eater-1 well in Block LB-09 offshore Liberia drilled with Ocean Rig’s semi-submersible rig, the Eirik Raude. The Bee Eater-1 well is located 9.5 km north west of the 2012 Narina discovery. AP could not move to the second well in this drilling programme with the same rig, because of the repeated failure of the rig’s Blow Out Preventer, which stretched drilling for 20 days more than could have been achieved.

Conoil, the Nigerian independent, successfully tested the first of two hydrocarbon filled reservoirs in its deep well in shallow offshore Nigeria. The company flowed in excess of 2,000BOPD of light oil in one of the two reservoirs in which it conducted Drill Stem Test in Ango 1Stk 3, in Oil Mining Lease(OML) 59. The tested reservoirs are located  between 15,400ft True Vertical Depth and 15,550ft TVD. This probe has opened up a whole new sequence in the southwestern, swampy part of the continent’s most productive basin.

Now to 2013…

Tullow has three rigs operating across Kenya and Ethiopia, including Weatherford-804  and Sakson PR-5One successfully completed testing Twiga South(2,800BOPD in three levels) as of late February 2013, another  drilled and suspended the Paipai well (both in Kenya)and the third was on the Sabisa well in Ethiopia. Tullow also plans to drill Kongoni structure, Twiga North and Kamba, all in Kenya, as well as Sabisa North and Tutule in Ethiopia. These aresome of the 11 exploration and appraisal wells in the region that Tullow hopes to drill in 2013. The company plans to carry out up to five well tests to de-risk further basins and to understand the potential scale of the South Lokichar discoveries.

The company is expected to test Ngamia 1 later in 2013. Ngamia-1is the basin opening well, drilled in early 2012. It encountered over 100metres of Net Oil Sands.

Ophir Energy plans to upgrade the Mbawa South lead offshore Kenya to a drillable prospect and drill the structure by second quarter 2013.The location is in Block L09 offshore Kenya

Meanwhile, Kenyan authorities insist that Vanoil Energy must commence drilling its first well in the country before July 31, 2013. With sufficient technical justification, the government says, the company  may place its first two wells anywhere within the boundaries of Block 3A and 3B to satisfy the work programme obligations within the Initial Exploration Period of its Production Sharing Contract (PSC).

OphirEnergy is planning to spud one of two wells in East Pande, in Tanzania’s shallow offshore Block 7, before the end of the First Quarter 2013.In the country’s deeper waters, however, the BG led BG/Ophir consortium has proposed two wells (4H and 4J)in Block 4, scheduled for drilling before March 31, 2013. In the second quarter, the partners will return to appraise the structures that have shown so much promise, as discoveries. They will be drilling one appraisal well each on the Chewa, Jodari and the Mzia structures. Jodari-1, drilled in 2012, was reportedly the partners’ largest discovery in Tanzania. With 124 metres of net pay “in two high-quality base Tertiary sandstone reservoirs”, Ophir thinks the well “de-risked Lower Tertiary section, of comparable age to outboard basin floor fan play in Mozambique” and exceeded “pre-drill mean estimate of 2.2 TCF by 55%”.

Tullow Oil’sNet production for 2012 from the East and West Espoir fields in Cote d’Ivoire averaged 3,400 BOEPD as natural field declines continue to be managed. A new drilling campaign of eleven infill wells (seven producers and four injectors) across the field is to start by the end of the first quarter of 2013.

In Angola, Cobalt Energy will drill six wells, some of them to appraise the Cameia-1 discovery. The company is hoping the results would convince government to sanction its plans for early production

Kosmos Energy anticipates spudding the Sipo-1 prospect, which is located onshore Cameroon on the Ndian River Block, in early February. Results from Sipo-1 are anticipated around the end of the first quarter 2013.

Equatorial Guinea-Ophir will pursue its lucky streak off the coast of this small, volcanic island on the Gulf of Guinea with three wells:  Silanius East, Viscale East and Helius East, all in the third quarter of  2013.

Ophir proposes to drill Manga MN1 prospect in its 100% operated Manga block offshore Gabon. There’s also a likelihood that Petrobras will drill the seemingly highly prospective Ntsina Padouck Deep in the Ntsina  Block. Tullow plans a two well exploration drilling campaign in the Kiarsseny Block,  to commence in the middle of 2013. Beyond exploration, the company expects “significant offshore and onshore drilling activity to continue on all fields in 2013, with a programme exceeding 60 infill wells across the Gabon portfolio”.

Statoil plans to drill two wells in Block 5, in the prolific deepwater offshore Mozambique, starting with the Cachalote well which is scheduled to commence drilling in Q2 using the Discoverer Americas rig.

North Africa:

PA Resources plans to drill an appraisal well on the Elyssa Field in Tunisia 2013, and an exploration well elsewhere in country’s offshore Zarat Permit.

Tullow’s drilling campaign in Mauritania, scheduled to commence in the second quarter of 2013, is designed to drill new deeper plays in the offshore Mauritanian basin which have not been tested by previous exploration wells. Three of the four wells are scheduled to be drilled in 2013 using the West Leo rig which has been operating in Ghana for Tullow. The Group believes that there is significant follow-on potential if any of these wells proves to be successful.

Longreach plans to drill its first well on the SidiMoktar permit onshore Essaouira Basin in Central Morocco in first half of 2013. In the same country, Circle Oil plans a six well drilling programme for first half of 2013 in the Sebou and Lalla Mimouna Permits. The campaign is aimed at boosting natural gas reserves on the acreages. Circle projects over 50% increase in gross production from 4.5MMscf/d to between 6.5 and 7.0MMsc/d in First Quarter 2013.

Meanwhile, the least likely drilling project on Kosmos Energy’s 2013 schedule is in Morocco.  The company, says that “first drilling offshore Morocco is targeted to commence as early as late 2013”.

Kosmos’ planned capital programme in the country provides for additional geologic studies, as well as further processing and interpreting of 3D data already acquired on the Agadir Basin Blocks. Included in the 2013 capital programme are funds for the completion of the Company’s acquisition of an additional 37.5 percent interest in the Essaouira Block.

Exxoil plans a two well drilling programme in Tunisia, including one well onshore on the Sedouikech prospect in the RasMarmour permit targeting 20 MMBO STOOIP and one well planned for the offshore Mahdia permit targeting up to 179 MMBO STOOIP. The proposed drilling on the Mahdia permit is the less certain of the two, as the operator only commenced, in mid February 2013, a 300 sq km 3D survey, to delineate the drilling location.

Vegas Oil and Gas’ 2013 work programme in Egypt includes the drilling of 4 further wells (1 producer and 3 injectors) in the first half of the year. The NW Gemsa Concession, containing the Al Amir and Geyad Development Leases, covering an area of over 260 square kilometres, lies about 300 kilometres southeast of Cairo in a partially unexplored area of the Gulf of Suez Basin.

© 2018 Festac News Press Ltd..