All posts tagged farm in-farm out


Indians to Take over FAR’s High Profile Assets in Senegal

By Toyin Akinosho

FAR has finally found a buyer for its high profile oil and gas asset offshore Senegal.

ONGC, the Indian state hydrocarbon company, has agreed to buy the property, which includes FAR’s entire interest in the Production Sharing Contract for the Rufisque, Sangomar, and Sangomar Deep Offshore Blocks offshore Senegal and the relevant Joint Operating Agreement (the RSSD Project).

The Sangomar exploitation project, located in these blocks, is the largest offshore crude oil development currently under construction in Africa. Phase 1 development of the project, which will develop some 250Million barrels of oil, remains on track for targeted delivery of first oil in 2023. Production from this phase is expected to be around 100,000 barrels of oil per day (BOPD).

The Australia listed minnow, which has struggled as a going concern-and has defaulted on paying cash calls on the project- in the last two quarters, says it has entered into a Sale and Purchase Agreement with ONGC (full name ONGC Videsh Vankorneft Pte Ltd), the largest E&P company of India, which has agreed to pay FAR $45Million at completion. In addition, ONGC has agreed to reimburse FAR’s share of working capital for the RSSD Project from 1 January 2020 totalling $66.58Million, payable on completion. The reimbursement is comprised of cash calls paid by FAR, including $29.60Million paid to cure FAR’s default to the Joint Venture. The Transaction also includes an entitlement to certain contingent payments capped at $55Million.

The Transaction is subject to conditions precedent, including the following:

  • The written approval of the Minister of Petroleum and Energies for the Republic of Senegal to the transfer of the Transferring Interest to the Purchaser being obtained. FAR hopes that such approval would be obtained in January 2021.
  • RSSD Project Pre-Emptive Rights – The Transaction is conditional on the waiver or non-exercise of preemption rights available to FAR’s co-venturers in the RSSD Project. FAR is issuing the pre-emption notices between November 11 and November 12, 2020, and the co-venturers have 30 days to advise if they wish to exercise their right to preempt the Transaction on the same terms and conditions as ONGC. In the event of pre-emption, FAR will receive the same consideration as from ONGC.
  • FAR Shareholder Approval – ASX Listing Rule 11 requires that FAR obtains shareholder approval in relation to the Transaction. FAR intends to convene a general meeting of FAR shareholders as soon as practicable to be held in December 2020 to consider approving the Transaction (including if the sale is the subject of pre-emption).
  • Third Party Agreement Termination – The Transaction is subject to the termination or satisfactory resolution of an agreement between FAR and a third party, details of which are currently commercial in confidence. ONGC has the discretion to waive this condition.

Cath Norman, FAR’s Managing Director, describes the offer from ONGC as representing “the best option available at this time and we trust that our shareholders will vote for this transaction”. She reinstates the well-known fact that “the market for financing and selling assets has been weak since the impact of COVID was felt in March of this year”.

If the Transaction completes, the company anticipates, “FAR will be in a strong financial position and will be relieved of its future development obligations in relation to the RSSD Project, which in the absence of a sale, FAR cannot currently meet beyond December 2020”.

FAR expects to have approximately $130Million in cash at the close of this Transaction that, Ms. Norman says,” will be used to rebuild the Company and further our other West African prospects offshore the Gambia and Guinea-Bissau”.

Having been in the RSSD project for 14 years, “it’s a bittersweet moment to be selling our stake. FAR is committed to our projects in The Gambia and Guinea-Bissau and using our deep knowledge of the MSGBC Basin to potentially explore offshore Senegal again,” Norman declares.


Angolan 2020 Onshore Bid Round Now to Open in January 2021

Angola 2020 Onshore Bid Round will officially open in January 2021 and bids must be submitted by March 10th 2021.

Nine blocks are on offer, in the Lower Congo and Kwanza Basins.

The country’s International Competitive Bid Round for oil gas licenses, announced last year, is a scheduled offering for onshore and offshore, in the period 2019-2025.

Last year, Angola’s National Agency of Petroleum, Gas and Biofuels (ANPG), awarded three blocks: 27, 28, and 29, offshore in the deepwater Namibe Basin.

This year, the bidding plans have been disrupted by COVID-19 complications.

The blocks on offer are CON1, CON 5, CON 6, KON 5, KON 6, KON 8, KON 9, KON 17 & KON 20 (See map here), located in the Lower Congo Basin and the Terrestrial Kwanza Basin.

Data available includes 2D seismic coverage of the LowerCongo Basin, a recently updated Geological Map and Database of the Onshore Kwanza Basin and a compilation of recent aeromagnetic data covering the Transition Zone and Shallow Waters of the Lower Congo and Kwanza Basins.

 

 


Africa Oil Makes $137.5Million in Seven Months, on Asset It Purchased for $519Million

Africa Oil Corp. concluded its acquisition – worth $519.5Million – for a 50% ownership interest in Petrobras Oil and Gas BV (POGBV) in January 2020.

Today, seven and half months later, it reports it has received  total dividends amount of $137.5Million since the closing of the Prime acquisition on 14 January 2020.

POGBV’s primary assets are an indirect 8% interest in oil mining lease (OML) 127, operated by Chevron, containing the Agbami Field, and 16% interest in OML 130, operated by TOTAL and contains the Akpo and Egina Fields, offshore Nigeria.

The Toronto listed minnow says it has received four dividends from Prime Oil and Gas B.V. (Prime) since the January 2020 purchase. Prime is a company that holds interests in deepwater Nigeria production and development assets.

On August 31, Africa Oil Corp. reported that Prime has distributed the fourth dividend, “a  $50Million dividend with a net payment to Africa Oil of $25Million related to its 50% interest”.

The Company has applied  $17.7Million of this dividend to pay down the BTG term loan, reducing the outstanding balance to  $176.9Million.

Africa Oil Corp. is a Canadian oil and gas company with producing and development assets in deepwater Nigeria; development assets in Kenya; and an exploration/appraisal portfolio in Africa and Guyana. The Company is listed on the Toronto Stock Exchange and on Nasdaq Stockholm under the symbol “AOI”.

 


Africa Energy Doubles Its Stake in South African Discovery

By Jo-Jackson Mthembu

Toronto listed minnow Africa Energy Corp., says it has signed definitive agreements to increase its effective interest in Block 11B/12B offshore South Africa from 4.9% to 10%.

Block 11B/12B is the site of the Paddavissie Fairway, on which TOTAL’s huge gas and condensate discovery was made in February 2019.

TOTAL is returning for a multi-well campaign in the block, located in the rough waters offshore Cape Agulhas, from September 2020.

“Block 11B/12B offshore South Africa contains one of the most exciting oil and gas exploration plays in the world today” Garrett Soden, the Company’s President and CEO, commented.

“In anticipation of the Luiperd-1X well results expected later this year, we have agreed with Impact Oil& Gas and Arostyle to simplify and consolidate Main Street’s 10% interest in Block 11B/12B under Africa Energy,” Soden said.

Luiperd-1, suspected to be the largest prospect in Paddavissie Fairway, will be the first on TOTAL’s drilling schedule. It will be drilled by the semisubmersible rig Deepsea Stavanger, operated by Odfjell Drilling.  Two other wells are expected to follow in short order.

Africa Energy currently holds 49% of the shares in Main Street 1549 (Proprietary) Limited, which has a 10% participating interest in Block 11B/12B. TOTAL operates the block with a 45% participating interest, while Qatar Petroleum and CNR International (have 25% and 20% participating interests, respectively.

Africa Energy says it is pursuing two transactions by which will first secure the indirect financial interest held by Impact Oil & Gas Limited and then obtain an option from Arostyle Investments (RF) (Proprietary) Limited, which holds 51% of the shares in Main Street, to acquire the entire Participating Interest after drilling the Luiperd-1X well. “Following the Impact Transaction and exercise of the Arostyle Option, subject to various consents and approvals, Africa Energy will directly hold the Participating Interest, and both Impact and Arostyle will be significant shareholders of Africa Energy”.

 


Senegal Expands its Stake in Sangomar Oilfield Project

Petrosen has decided to increase its stake in the Sangomar Exploitation Area from 10% to 18%.

Senegal’s state hydrocarbon company is now required to reimburse the other venturers in the Rufisque, Sangomar and Sangomar Deep (RSSD) acreage their pro-rata share of the 8% of expenses relating to the Sangomar Exploitation Area incurred since 8 January 2020.

“As a result, FAR’s stake in the Sangomar Exploitation Area decreases from 15% to 13.67%”, FAR says in a release.

Woodside Energy, the operator, holds 31.89%; and Cairn Energy has 36.44%. Russian giant Lukoil agreed to buy out Cairn Energy’s interest, but Woodside has invoked the right of first refusal. Woodside will now purchase Cairn’s 36.44% by paying $300Million upfront, plus working capital adjustments, including reimbursement of Cairn’s development capital expenditure incurred since 1 January 2020.

Work on the Sangomar Field Development commenced in early 2020 and first oil production is targeted in 2023.

FAR, an Australian junior, has struggled to pay its part of the cost of the project on an ongoing basis and has stated, time and again, that it is willing to sell some or its entire equity.


Conoil Wins Bid for Chevron’s Sale of Equity in OMLs 86 and 88

By Jo-Jackson Mthembu, in Yenagoa

Conoil Producing, the Nigerian E&P independent owned by the billionaire Mike Adenuga, is the winner of the bid for the 40% equity held by Chevron Corp. in Oil Mining Leases (OMLs) 86 and 88.

The Lagos based junior is currently in discussion with the California headquartered major.

It wasn’t clear, as of the time of this writing, how much Conoil is betting on the assets, which lie in contiguity with some of its own producing properties.

Chevron had been trying to dispose the shallow water acreages, located off the mouth of the current Niger Delta basin, for over five years. They are part of the five Nigerian tracts acquired in the course of the merger between Chevron and Texaco 21 years ago.

But things only revved up in the last seven months. Africa Oil+Gas Report disclosed, three months ago, that bidders were expected to make full disclosure of their financial and operating capacities by the end of April 2020.

OML 86 contains the Apoi fields; the largest being North Apoi.

It also holds Funiwa, Sengana and Okubie fields. One recent discovery: Buko, straddles Shell Nigeria operated Oil Prospecting Lease (OPL) 286 and is either on trend with, or on the same structure as the HB field in OPL 286. OML 88 holds the Pennington and the Middleton fields, as well as the undeveloped condensate discovery, Chioma field.

The conclusion of this sale means that Chevron has disposed of all the legacy shallow water assets it acquired when it purchased Texaco in 1999.

Between 2013 and 2015, Chevron sold its stakes in OMLs 83 and 85, both of them former Texaco Nigeria assets.

It’s instructive, then, that Chevron’s largest producing asset in Nigeria, the Agbami field, was “inherited” in that same turn- of –the- century merger with Texaco; this deepwater field alone produces 165,000BOPD, more than a third of Chevron’s total operated crude oil production in Nigeria.

 


High Number of Offshore Fields Increases the Risk in 2020 Marginal Field Bid Round

By Fred Akanni, Editor in Chief

There are 29 shallow water fields among the 52 fields on offer in the ongoing Nigerian marginal field bid round, which wraps up on September 2, 2020.

This represents 56% of the total.

Compared with six offshore fields (or 25%) out of the 24 marginal fields offered in 2003/2004, this current round is enormously riskier.

Offshore fields are more expensive.

An average 20Million barrel field in 30 metres of water will require in excess of $65Million to reach first oil, according to modelling by Africa Oil+Gas Report.

In the last marginal field round, offshore fields represented the highest proportion of the fields that didn’t make it to first oil.

Out of the six offshore fields (all located, incidentally, in acreages operated by Chevron) awarded in 2004, only one made it to first oil.

The fields with the fastest routes to market, in the class of 2004, are located on land. Most of those that struggled to reach first oil, are in swamp terrain.

Details on funding challenges and opportunities in the July 2020 issue of Africa Oil+Gas Report.

 


Energy Chamber Campaigns for Chevron’s “Entry” into Eq Guinea’s Gas Project

Chevron’s ongoing take- over of the US independent Noble Energy offers it the opportunity to lead a significant gas project in the Equatorial Guinea and Cameroon.

These two countries, along with Israel, make up the international portfolio on the list of properties, up for Chevron’s grab, in the $13Billion take over. As Africa Oil+Gas argues in its July 2020 issue, the California based major has prioritized the unconventional basins in the US as the raison dêtre for seeking to buy Noble Energy. Eq Guinea and Cameroon are a little below the radar in its ranking.

But the African Chamber of Energy (ACE) sees the bright side for the African opportunity. It is encouraging the authorities to facilitate Chevron’s entry into Central Africa’s “most ambitious gas project” through this take over.

Noble Energy has interests in the Alba Field (33% non-operated WI and 32% revenue interest), Block O (Alen Field 51% operated WI and 45% revenue interest) and Block I (Aseng Field, 40% operated WI and 38% revenue interest).

“While the Alba Field has been feeding gas into the country’s Punta Europa complex for decades, including the EG LNG Plant, the AMPCO methanol plant and the Alba LPG plant, its declining reserves have led to the development of the Alen and Aseng fields as alternative sources of gas”, the Chamber recalls. “In 2019, Noble Energy was at the heart of a groundbreaking agreement to launch the Alen Monetization Project, expected to ensure continued and stable gas supply to Equatorial Guinea’s LNG and downstream revenue-generating infrastructure.

ACE appeals that “transaction and projects approvals should not be unnecessarily delayed ensuring a quick and efficient takeover in the region so ongoing gas projects are not delayed.”

NJ Ayuk, the Chamber’s Executive Chairman and Kickstarter, declares: “This acquisition gives the region a very experienced and credible gas player with tried, true and tested solutions to support our gas ambitions. ‘Fast tracking approvals and driving commonsense measures around this deal will make the industry work.”

Although ACE says that “these assets in Equatorial Guinea represent 94Million barrels of oil equivalent of proved developed reserves and 38Million barrels of oil equivalent of proved undeveloped reserves”, Noble Energy, on its website, talks of three trillion cubic feet of gross natural gas resources in the Douala Basin, “which positions us well for LNG sales exposure over the coming decade”.  Three Trillion Cubic Feet translates to 500Billion BOE. So, the chamber’s figures don’t add up. Not good enough for a supposedly optimistic release. ACE adds: ”In addition, Noble Energy was also the operator Block YoYo in Cameroon and of the deepwater Block Doujou Dak (60% WI) in Gabon, where it was in the process of evaluating recently acquired 3D seismic data.

“The project is still on track for delivery in 2021 and is the first step of the development of a much broader offshore gas mega-hub in the Gulf of Guinea. This regional gas hub would ultimately include the development of the Yolanda and YoYo discoveries located in Equatorial Guinea’s Block I and Cameroon’s YoYo Block, both operated by Noble”.

Noble Energy explains on its website: A 24-inch pipeline capable of handling 950 million cubic feet of natural gas equivalent per day (MMcfe/d) will be constructed to transport all natural gas processed through the Alen platform approximately 70 kilometers to the onshore facilities.

At start-up, natural gas sales from the Alen field are anticipated to be between 200 and 300 MMcfe/d, gross (~75 to 115 MMcfe/d net to Noble Energy)

The reserves figures may look impressive, from where ACE sits, but American companies, as a rule, and Chevron is a good example, have, in the last five years tilted to E&P developments at home than abroad.

Ayuk calls for “a pragmatic commonsense approach that welcomes credible investors and see gas taking the lead in economic development and industrialisation, therefore the entry of Chevron is extremely welcomed and should be accepted by all stakeholders.”

“From its Nigerian and Angolan presence, Chevron understands the issues and opportunities of developing African content. We expect its entry to be beneficial from a local content and capacity building perspective,” said Leoncio Amada NZE, President for the CEMAC region at the African Energy Chamber. “We hope that the authorities in Cameroon and Equatorial Guinea can do an efficient and fast track the due diligence process and ensure that Noble meets all its obligations to exit and create a seamless transition for Chevron. This is an opportunity for our public authorities to demonstrate their commitment to empowering investment and move away from an era of uncertainty to give confidence to future investors and stay competitive”.

ACE is full of praise for Chevron’s leadership in African natural gas development. “Chevron is indeed a true gas player in the African market. In Nigeria, Chevron has been leading natural gas commercialization efforts for decades through its Escravos projects targeted the monetization of 18Tcf of gas. These have resulted in the Escravos Gas-to-Liquids facility and the Escravos Gas Plant, both cornerstones of Nigeria’s gas development strategy. In Angola’s Block 0 and Block 14, Chevron has demonstrated a remarkable ability to invest in cutting flaring and monetization gas. In block 0, it still operates what is the world’s largest LPG FPSO vessel, turning previously flared gas into cleaner fuels for Africans and the for the world.”

 

 

 


Oriental Proposes Sale of Equity in Nigerian Assets

Oriental Energy Resources has commenced a marketing campaign of certain interests in its existing offshore Nigeria assets to qualified prospective partners, having recently obtained Government approval for its legacy block Oil Mining Lease (OML-115) for a new twenty-year term under terms which include a zero-relinquishment provision.

OML-115 includes an oil discovery adjacent to the Okwok Field, and several large potential exploration prospects defined by a block-wide circa $40Million state of the art four-component 3D seismic survey acquired in 2012, the same seismic data set that was used to define Oriental’s recent successful exploration well Ebok-45, that has tapped a significant new pool of light oil in acreage adjacent to OML-115.

Oriental is an indigenous offshore (marginal field) operator and oil producer, and the 100% interest owner of OML-115 and the Ebok Field in OML-67, and the 88% interest owner of the Okwok Field in OML-67.   In Oriental’s nearly 30-year history, it has partnered with Conoco, Nexen, Mobil-NNPC, Addax Petroleum, Energy Equity Resources, and Afren Plc.

Oriental’s recent Ebok-45 Deep Discovery promises to deliver a potential recoverable reserve of a similar or greater scale than both Ebok and Okwok Fields.

“Oriental has been responsible from Day One to maintain all of its licenses in good standing with the Government, to acquire all permits and licenses for the circa $4Billion Ebok Development and its 45 wells drilled to date”, the company says in a note to investors.

“Since 2015 Oriental has completed the acquisition of 100% of the Ebok Field equity, and is bearing 100% of the Ebok Field production costs” Oriental explains, “as well as the recent deep exploration discovery well costs and of the future planned Ebok exploration and appraisal drilling programme”.

The Okwok Field is currently under development with a well-head and FPSO development solution that has its FDP approved and under way to deliver First Oil in mid-2021. From Oriental’s recent organic exploration successes and the conservative reserve potential Oriental anticipates achieving gross production from the combined Ebok and Okwok Fields of circa 50,000BOPD by year-end 2023 and has set a corporate goal of attaining 100,BOPD by year-end 2028.

This article was originally published in the May 2020 edition of Africa Oil+Gas Report.

 


Nigerian Bid Round: DPR Says ‘Hold on, We’d Communicate Soon’

Nigeria’s Department of Petroleum Resources (DPR) says it will communicate the next steps of the ongoing bid round of marginal fields soon.

Several of the 500+ companies who have been notified of their prequalification had fruitlessly attempted to access the portal, on Monday and Tuesday, to pay for the next step of the round.

But officials at the regulatory agency told Africa Oil+Gas Report, they were still dealing with matters arising over the pre-qualification process and that access to the portal was closed for now.

The portal itself, on the DPR website, says: “Next step of the bid round to be communicated, soon”.

For the purpose of further payments, the notice on the portal adds: GIFMIS Code for Application Fee: 1000289370 and GIFMIS Code for Bid Processing Fee: 1000289383.

The matters arising that the officials spoke about has to do with the fact that there were companies who could make the qualification, but who are owing government a tax, tariff, fee or the other. A company may have fulfilled all obligations to government, but a director on its board may be a director in another company that is delinquent in paying statutory fees. Prequalificiation of such a company is on hold until the director clears himself.

Companies so affected have to comply by close of business on Friday, July 24, 2020.

In effect, the Nigerian government has taken advantage of the bid round to reclaim some of the debts owed to it.

As an update to our last report, there are no clear schedules for the remaining steps of the bid round, now.  The best thing to do is keep visiting the website of the DPR, https://www.dpr.gov.ng/

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