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TOTAL Takes Over Moza LNG

The French supermajor will lead the largest greenfield LNG development project in Africa

TOTAL has closed the acquisition of Anadarko’s 26.5% operated interest in the Mozambique LNG project and will now be leading the development of the proposed 12.8Million Ton Per Annum (12.8MMTPA) facility.

The Mozambique LNG will valourise some 2Billion standard cubic feet of natural gas per day (2Bscf/d), making it the continent’s largest gas project currently in development.

The French major closed the takeover deal, which includes acquisition of Anadarko’s assets in Algeria, Ghana and South Africa, for a purchase price of $3.9Billion.

TOTAL says it has now received all requisite approvals by the relevant authorities and partners, for the transactions.

The purchase, which now makes TOTAL the largest E&P operator in Africa, commenced on  May 3, 2019, when the Paris based firm reached a binding agreement with Occidental, which was about to buy up Anadarko, to take over all of Anadarko’s interests in Africa. On August 3, 2019, TOTAL signed the subsequent Purchase and Sale Agreement.

TOTAL is taking over the Mozambique LNG project after financial sanction.

The Final Investment Decision for the project was taken in June 2019. The announcement, by Anadarko and the co-venturers in Mozambique’s Offshore Area 1, “confirmed the Area 1 Plan of Development was now effective, with notice provided to the Government of Mozambique that all conditions precedent have been fulfilled, and the project can now advance to the construction phase”, Anadarko said at the time. It would monetise over 75Trillion cubic feet of natural gas in the Golf-Atinho fields in the deep-waters of the Indian Ocean.

The project had successfully secured in aggregate 11.1 MMTPA of long-term LNG sales (representing 86% of the plant’s nameplate capacity) with key LNG buyers in Asia and in Europe. Additionally, the project is expected to have a significant domestic gas component for in-country consumption to help fuel future economic development.

As the new operator take over Africa’s largest greenfield LNG project, Patrick Pouyanné, Chairman & CEO of TOTAL, says the company “will bring the best of our human, technical, marketing and financial capacities to further strengthen its execution. He says that TOTAL “will of course work on the strong foundations established by the previous operator and its partners, in order to implement the project in the best interest of all those involved, including the government and the people of Mozambique.”

 


No Go Ahead Yet For Nigerian Licensing Round

By Fred Akanni, Editor in Chief

There is no plan yet in President Muhammadu Buhari’s second term, to propose any open licencing round of Nigeria’s upstream hydrocarbon property.

“It’s too early in the tenure of the Minister of State (Timipre Sylva), who resumed duties on August 20, 2019”, say ranking officials at the Ministry of Petroleum Resources in Abuja, the country’s political capital.

“Proposals for Bid Rounds are always routed through the office of the Minister of State”, a ministry official told Africa Oil+Gas Report in Abuja “At the moment, he hasn’t received one”.

Mr. Sylva has talked on record about certain issues, including sale of NNPC assets (“We have not decided we would do it”) and Petroleum Industry Bill (“I’d work with experts to deliver it”), but he hasn’t specifically mentioned a licencing sale.

Nigeria has not had a licensing round in the last 12 years. The country’s exploration activity is on a downslope, with 31 of 33 active rigs in the country’s basins working on development drilling, and hardly any appraisal. Over 35 prospecting and mining leases, some of them having been held by companies for as long as 27 years, are lying fallow, without any robust work programme.

Asked if the issue of licensing round was discussed at the two day retreat the Minister of State had with the directors and chief executives of the Ministry two weeks ago in Abuja, several sources within the Ministry and the NNPC, the state hydrocarbon company, said it was not. But for the record, Africa Oil+Gas Report was told: “What was discussed at the retreat, stays at the retreat”.

 


Sonangol Preps for First Presentation on Sale of Assets

By Veronica Gespucci, in Windhoek

Sonangol will be making its first technical presentation to the public on its planned asset sale in October 2019.

It will be in Luanda.

The Angolan state hydrocarbon company will be selling equity or whole in a total of 50 subsidiary companies and other assets, twenty of them in 2019.

The sale is part of the Privatisation Programme (ProPriv), which lists 195 state-owned enterprises to be fully or partially privatised by 2022.

There will be a roadshow in Dubai after the Luanda outing.

Sonangol -owned assets make up about a quarter of the entire Privatisation bucket list. The once powerful state energy firm will dispose of 20 companies and assets by December, with 26 planned to be sold by 2020, three in 2021 and one in 2022.

The list includes divestments in the subsidiaries and assets of Sonangol Cabo Verde – Sociedade e Investimentos and Óleos de São Tomé and Príncipe, as well as stakes in Founton (Gibraltar), Sonatide Marine (Cayman Islands), Solo Properties Knightbridge (United Kingdom), Societé Ivoiriense de Raffinage (Cote d’Ivoire), Puma Energy Holdings (Singapore) and Sonandiets Services (Panama), by 2021.

Sonangol will sell also its stake in WTA-Houston Express and French company WTA, as well as assets in Portuguese real estate companies Puaça, Diraniproject III and Diraniproject V, in Sonacergy – Serviços e Construções, Sonafurt International Shipping and Atlantis Viagens e Turismo.

Sonangol also holds assets to be privatised in Angolan companies in the Health, Education, Transport, Telecommunications, Energy, Civil Construction, Mineral Resources and Oil and Banking sectors.

Sebastião Gaspar Martins, Sonangol’s non executive chairman, says the sale of these non-core assets will make the company “financially more robust.” Sonangol is expected to have the wherewithal, going forward, to focus on hydrocarbon properties.

 


LEKOIL Looks For Partner to Take Over Disputed 23% Stake in OPL 310

LEKOIL has agreed with Optimum, its partner in Oil Prospecting Lease (OPL) 310, in deepwater Nigeria, to use its 22.86% equity stake in the Block as a potential funding and security vehicle for the accelerated development of the Block by an industry partner or a third party that elects to farm-in to the Block to fund field development.

The AIM listed LEKOIL has a 17% equity on the lease that has been authorised by the Nigerian authorities, but has been unable to get the consent of the government for another 22.86%, equity, which it purchased with $13Million from Afren in 2015, mainly because Optimum, the holder of the licence (who sold the stake to Afren in the first place), disagrees that LEKOIL had legitimately bought the equity from Afren.

“This dispute has been the principal reason that development of the Block has been delayed”, LEKOIL says in a release.

LEKOIL had taken the President of Nigeria (who is the Minister of Petroleum) to court over the non-granting of consent for that equity for four years. It lost the case and decided not to appeal.

“Rather than pursue this matter further, the Parties have agreed to recourse to sourcing a third party that will bring money to fund the appraisal and development of the field”, LEKOIL explains.

The resource estimates of the Ogo field, the undeveloped discovery in the licence, is 750Million barrels of oil equivalent. The two probes on the structure were not tested, so the volumes could be less. But they also could be more and there’s the perception that most of it is natural gas, which now has a growing market in Lagos, the nearest city inshore of the field.

The potential Funding Partner may be sourced by either LEKOIL or Optimum. The agreement does not address the recovery of the $13Million consideration previously paid by LEKOIL with respect to the acquisition of the shares of Afren Oil & Gas (Nigeria) Limited (“AOGNL”) in 2015 (which held the 22.86% participating interest in OPL310). The idea is that this money will be part of the farm in consideration to be taken care of by the incoming funding partner.


‘They Don’t Want to Pay Taxes’, Ugandan Government Asserts

By Toyin Akinosho, Publisher

FID for basin-wide development likely to be postponed far into 2020

The termination of Tullow Oil’s farm down from the Ugandan oilfield project was essentially about disagreement with the authorities on Tax payment.

The press release by TOTAL is vague on this specific detail, only saying that “no agreement on the fiscal treatment of the transaction has been reached”.

Tullow’s statement is more pointed about the issue: “this transaction is a result of being unable to agree all aspects of the tax treatment of the transaction with the Government of Uganda which was a condition to completing the Sale and Purchase Agreements SPAs”.

The British minnow then goes on to exonerate itself:

“While Tullow’s capital gains tax position had been agreed as per the Group’s disclosure in its 2018 Full Year Results, the Ugandan Revenue Authority and the Joint Venture Partners could not agree on the availability of tax relief for the consideration to be paid by TOTAL and CNOOC as buyers”.

Meaning that the two huge firms: the French supermajor and the Chinese behemoth didn’t consent to the tax that the Ugandan government wanted from them.

Ugandan authorities flatly debunk this exoneration.

“Tullow sought transfer of its interest without payment of any capital gains tax arising from the sale and also on condition that certain tax deductions, not ordinarily transferable to the buyers, be transferred to the buyers”, says Robert Kasande, Permanent Secretary at the Ugandan Ministry of Energy and Mineral Development.

Kasande’s statement declares that the Government of Uganda had drawn the line clearly since over a year now, but the private parties simply didn’t come to the party.

Following several engagements with the partners (TOTAL, Tullow and CNOOC), “Uganda Revenue Authority communicated its tax assessment on 10th August 2018. Government’s position is that the assessed tax should be paid in line with the laws of Uganda and tax reliefs are treated in accordance with the laws of Uganda”.

Tullow will now initiate a new sales process to reduce its 33.33% Operated stake in the Lake Albert project which has over 1.5Billion barrels of discovered recoverable resources and is expected to produce over 230,000BOPD at peak production.

Ugandan authorities are hoping that this termination does not unduly delay a Final Investment Decision for the project, but Tullow warns: “The Joint Venture Partners had been targeting by the end of 2019, but the termination of this transaction is likely to lead to further delay”.

 


TOTAL Terminates Ugandan Agreement with Tullow

French major TOTAL has terminated its agreement to purchase stakes belonging to British minor Tullow in the Ugandan oilfield project.

TOTAL cites inability to reach common ground on the farm in/farm out, with the Ugandan authorities.

“On January 9, 2017, TOTAL and Tullow entered into a Sale and Purchase Agreement (SPA) whereby TOTAL would acquire 21.57% out of Tullow’s 33.33% interest in the Lake Albert licenses. CNOOC exercised its right to pre-empt 50% of the transaction. As a result, TOTAL and CNOOC would have each increased their interest to 44.1% while Tullow would have kept 11.8%”, TOTAL explains in a release today.

“Since 2017, all parties have been actively progressing the SPA.

“However, despite diligent discussions with the authorities, no agreement on the fiscal treatment of the transaction has been reached.

“The deadline for closing the transaction has been extended several times, clearly demonstrating the endeavours of the parties to find an agreement. The final deadline will be reached at the end of today, August 29, 2019, and as such, the Acquisition Agreement will be automatically terminated”.

TOTAL further avers that “despite the termination of this agreement, TOTAL together with its partners CNOOC and Tullow will continue to focus all its efforts on progressing the development of the Lake Albert oil resources. The project is technically mature and we are committed to continuing to work with the Government of Uganda to address the key outstanding issues required to reach an investment decision”.

In that release, Arnaud Breuillac, TOTAL’s President Exploration & Production declares: “A stable and suitable legal and fiscal framework remains a critical requirement for investors”.

TOTAL says its interest “will therefore remain at 33.3% on blocks EA1, EA2 and EA3 prior to the 15% national company back-in, TOTAL being operator of the block EA1 which contains the largest part of the reserves”.

The company “keeps the right to pre-empt any future transactions, in case any party divests part or all of its interest”, it maintains.

 

 


Shell Gets Positive Judgement on OML 11

By Fred Akanni, in Lagos

The Federal High Court in Abuja, Nigeria on Friday, August 23, 2019, ordered the Minister of Petroleum Resources to grant the renewal of the Oil Mineral Lease (OML) 11 to Shell Petroleum Development Company of Nigeria for 20 years.

Justice Taiwo Taiwo, in his judgment delivered in a case tabled by the AngloDutch company, ruled that renewal would be for 20 years and not 30, as requested by Shell.

Shell’s prayers to the court were against the Minister of Petroleum Resources and the Minister of State. President Muhammadu Buhari doubles as the Minister of Petroleum Resources.

Abba Kyari, President Buhari’s highly powerful chief of staff had, in a letter dated March 1, 2019, written the Group Managing Director of the state hydrocarbon company NNPC to note that President Buhari had “Directed the NNPC/NPDC to take over the operatorship, from Shell Petroleum Development Company, of the entire OML 11, not later than 30, April 2019 and ensure smooth re-entry given the delicate situation in Ogoniland”.

At the time the order was given, Shell was still processing the renewal of the OML 11 licence.

Shell was also, at the time, in negotiations with the Nigerian multi-sectoral company Transcorp, to sell its stakes in the lease to the latter, in the event of the renewal. Some other Nigerian and international companies were considering raising the $1Billion invoice that Shell had presented to Transcorp, for its stakes in OMLs 11 and 17, until Mr. Kyari laid down the gauntlet.

Mr.Kyari’s letter did not contain the word “revoke” and since it only talked about NNPC taking over “operatorship”, a consensus grew that Shell had been granted renewal, but not operatorship.

The arguments in the suit that was decided last Friday, have proved the contrary.

If the government does not appeal the court case, Shell would likely proceed to sell the 45% belonging to it and TOTAL and ENI, in those two acreages.

A secondary lease sale market has grown large in Nigeria in the eleven years since Oando acquired stakes in two Shell operated deepwater leases, in 2008. The market is fed by the lacuna caused by the absence of licencing round in the country since the end of President Olusegun Obasanjo’s tenure in 2007.

The Nigerian treasury itself has not exactly benefited from these sales, as had happened in farm-ins and outright asset sales in Uganda, Angola and Libya in the course of the last 10 years. When the Department of Petroleum Resources staked a claim, for the first time, to 10% of the transaction money, in the last Shell-led bid round, (2014-2015), which grossed $4.6Billion, it discovered a clause in the transaction that said that any payment to government from the deals had to be made by the buyers of the assets. And since the buyers are “poor” Nigerian companies, the DPR found itself on the back foot.

 


Savannah Gets Buhari’s Nod to Take Over Seven Energy

The British independent Savannah Petroleum PLC, says that President Muhammadu Buhari has approved the transfer of the ‘Seven Assets’ (Seven Energy International Limited (SEIL)’s entire interests in Seven Uquo Gas Limited, Universal Energy Resources Limited and Accugas Limited), to Savannah Petroleum.

The notification came from the Nigerian Department of Petroleum Resources.

The Consent is subject to the payment of all taxes due in relation to the Transaction within 90 days of the receipt of the approval letter conveying the Consent.

“The receipt of the Consent represents the satisfaction of a significant condition precedent for the Transaction”, Savanah Petroleum explains.

“The principal remaining conditions precedent for the Transaction relate to the execution of long-form documentation in relation to the Accugas debt restructuring and the Frontier Swap, following which the Transaction completion process is expected to commence”.

This completion process will follow pre-agreed steps as set out in the legally binding Implementation Agreement which was signed in February 2019.

The Seven Energy Transaction refers to the planned acquisition by Savannah of the Seven Assets and the restructuring of Seven Energy’s existing indebtedness, specifically relating to the gas for oil swap with Frontier Oil Limited, the buy-out of minority shareholders in Universal Energy Resources Limited, the acquisition of an additional 55-60% interest in Accugas as well as the sale of a 20-25% (less one share) interest in Seven Uquo Gas Limited SUGL and Accugas to African Infrastructure Investment Managers AIIM.

 


Chinese Grab A Chunk of Svenska in Guinea Bissau

Chinese behemoth CNOOC is set to acquire 55.55% interest from Svenska Petroleum in Block 2, the Sinapa Licence, and Blocks 4A & 5A, the Esperança Licence, offshore Guinea Bissau.

Under the terms of the farm-out agreement, CNOOC will be assigned a 55.55% participating interest in the acreages, with the obligation to fund 55.55% of all expenditures under their respective Agreement for Joint Venture Participation (AJVP) and Joint Operating Agreements (JOAs).

CNOOC’s interest will convert to a 50.0% participating interest in each of the licences in the event of a commercial discovery.

Subject to receiving regulatory approvals, the transaction is expected to close in the third quarter of 2019.

The Swedish based player Svenska will retain a reduced 23.03% participating interest and shall continue to act as operator while CNOOC, upon conclusion of the upcoming offshore drilling campaign, may elect to assume operatorship. FAR, the Australian explorer, continues to hold its 21.42% participating interest in each of the licences.

Completion of the farm-out agreement is subject to approval from the Government of the Republic of Guinea-Bissau and customary Joint Venture consents which, under the AJVP, is not subject to pre-emption rights.

Svenska will continue to operate the exploration licences as the JV prepares to drill the first ever deepwater exploration well offshore Guinea-Bissau in the first quarter of 2020.

“Drill planning is on target to test Greater Atum Prospect (471MMbbls*, 100% basis, best-estimate prospective resource) in Q1 2020”, says FAR. “Greater Atum is a shelf-edge combined structural-stratigraphic play analogous to giant SNE oil discovery offshore Senegal”.

Past offshore exploration in Guinea-Bissau had initially concentrated in shallow waters less than 200m, targeting a variety of salt diapiric-related features. “Drilling to date has encountered excellent quality reservoir sands across multiple intervals exhibiting abundant oil and gas shows”, FAR indicates in a report. The Sinapa permit has two discoveries, with light oil having been recovered to surface from both those locations. The more significant of the two is the Sinapa discovery with contingent resources of ~13.4MMbbls* of recoverable light oil (unrisked, 2C case, 100% basis).

The Greater Atum will be the first offshore exploration well drilled since 2007 and the first ever deepwater exploration well offshore Guinea-Bissau.

CNOOC Limited, (together with its subsidiaries) is the largest producer of offshore crude oil and natural gas in China and one of the largest oil and gas exploration and production companies in the world.


The Lead Hunter Exits the Jungle

By Toyin Akinosho

Anadarko has led the hunt for elephant size oilfields in the African frontier for a good part of the last two decades.

By this time next year, the company would have ceased to exist, with its entire shares purchased by Occidental Corp., which in turn would have sold the African portfolio to TOTAL, the French major.

What we will be left with are only memories of how the Texas based independent foraged the jungle, opening up basins long deemed un-prospective and inaugurating a class of American/European headquartered independents who have come to consider Africa as their primary heartland.

Anadarko has had a longer presence in Africa’s high profile hydrocarbon economies than Apache Corp, Tullow Oil, or any of the leading western independents currently on the prowl for game on the continent. It drilled its first well in Algeria in 1991 and made its first oil discovery in 1993.  In 1995, SONATRACH approved the first development plan, and production began in 1998. It is also  more of a wildcatter than the other leading Western independents operating in Africa.

Anadarko leads any other foreign company in Algerian hydrocarbon output, with 24.5% participating interest and operatorship of blocks 404a and 208 (Hassi Berkine, Ourhoud and El Merk fields) in the Berkine basin.  These fields represented a gross production of three hundred and twenty thousand barrels of oil equivalent per day (320KBOEPD) in 2018.

Anadarko was on the foundation floor of Ghana’s joining the ranks of the world’s sizable oil producers. In 2007, it funded, largely, the drilling that led to the discovery of the Jubilee field in Ghana and proceeded to “decode” the deepwater Sierra Leone-Liberian basin with two discoveries (2009/2010). These outcomes re-awakened the global earth science consciousness of the West African Transform Margin.

The company led the way into Mozambican deepwater, in 2010, when it opened the Rovuma Basin with discoveries of three large gas fields: Windjammer, Barquentine and Lagosta, back to back. ENI drilled its own prospects in the same deepwater Rovuma Basin, a year later, and for those efforts, Mozambique is on its way to become the fifth largest exporter of LNG, by 2025.

Anadarko chased the opportunities it sighted in Ghana into neighbouring Cote d’Ivoire, where it discovered the Paon field in 2012.

But even the most talented super hunter sometimes returns home empty handed.

The attempt to find the onshore extension of the Rovuma fairway in Mozambique ended in a cul de sac. In 2015, five years after the discoveries of those large tanks offshore. The American independent h finalised the drilling of two wells, in the space of two months, without commercial success. Kifaru-, the second well, was even more disappointing than Tembo-1, which encountered relatively thin gas footage.

Nor could Anadarko go any further than wildcat drilling in the Sierra Leone-Liberian Basin. The Venus B-1, with 14 metres net hydrocarbon pay and the Jupiter-1, with 30 meters of hydrocarbon pay, did not indicate sufficient commerciality for the company to proceed to appraisal.

Anadarko also failed in Kenya, where its Kubwa-1 well, in the L-07 Block offshore Lamu Basin, encountered non-commercial oil shows in reservoir-quality sands.

In Cote D’Ivoire, after two promising appraisals, the Paon structure, its satellite prospects and other plays in Anadarko’s other operated blocks in the country, began to act up. The Paon-6A appraisal well, an up-dip appraisal of the South Channel, did not encounter hydrocarbons. And Anadarko could not find commercial quantities of hydrocarbons in the Colibri-1X exploration probe, which had looked so promising on seismic.  After further evaluation of the well results, in the last quarter of 2017, the Company withdrew from all blocks in the country.

The oil price crash of 2014 affected Anadarko, like most of its peers. In that year it reported a loss of $1.75Billion.

Anadarko has, for most of the last five years averted its gaze from wildcatting in Africa and focused, mostly, on the Shale belt in the United States, as well as on the value that could be generated from its largest asset on the continent: the 75Trillion cubic feet of gas nestled in less than 1,7000metres of water in the Indian Ocean.

That is the biggest haul that any company buying Anadarko’s African Portfolio would be harvesting.

 

 

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