News

Oil giant Shell strikes deal to buy power from ‘world’s largest offshore wind farm’

Shell said Wednesday it had signed a deal to purchase power from a development dubbed “the world’s largest offshore wind farm.”

The 15-year power purchase agreement relates to 240 megawatts from Dogger Bank C, the third and final phase of the 3.6 gigawatt Dogger Bank Wind Farm, which will be located in waters off the coast of northeast England.

The agreement builds upon a previous deal to purchase 480 MW from Dogger Bank A and B, meaning that its combined offtake will amount to 720 MW.

On Wednesday, Dogger Bank Wind Farm announced it had also agreed 15-year power purchase agreements for Dogger Bank C with Centrica Energy Marketing & Trading, SSE Energy Supply Limited and Danske Commodities.

“The commercial power agreements provide a route to sell the green energy generated by the third phase of the wind farm into the GB electricity market when it enters commercial operation,” it said.

Dogger Bank A and B represents a joint venture between Equinor, SSE Renewables and Eni, with the companies holding stakes of 40%, 40% and 20% respectively.

This month, it was announced Eni would also acquire a 20% stake in Dogger Bank C, with Equinor and SSE Renewables each holding on to a share of 40%. This deal is slated for completion in the first quarter of 2022.

“Once the three phases are complete, which is expected by March 2026, Dogger Bank will be the largest offshore wind farm in the world,” Dogger Bank Wind Farm says.

Despite making deals related to renewable energy, Shell remains a major player in oil and gas. It has pledged to become a net-zero emissions energy firm by 2050.

In February, the business confirmed its total oil production had peaked in 2019 and said it expected its total carbon emissions to have peaked in 2018, at 1.7 metric gigatons per year.

In a landmark ruling earlier this year, a Dutch court ordered Shell to take much more aggressive action to drive down its carbon emissions and reduce them by 45% by 2030 from 2019 levels.

The verdict was thought to be the first time in history a company has been legally obliged to align its policies with the 2015 Paris Agreement. Shell is appealing the ruling, a move that has been sharply criticized by climate activists.

In October, billionaire activist investor Dan Loeb called on the business to break up into multiple companies to strengthen its performance and market value.

Shell acknowledged Loeb’s letter to clients calling for the company to split, saying it “regularly reviews and evaluates the Company’s strategy with a focus on generating shareholder value. As part of this ongoing process, Shell welcomes open dialogue with all shareholders, including Third Point.”

More recently, in mid-November, Shell said it would move its head offices to the U.K. from the Netherlands, and ditch its dual share structure. Under these plans, the firm’s name would change from Royal Dutch Shell plc to Shell plc.

“The simplification will normalise our share structure under the tax and legal jurisdictions of a single country and make us more competitive,” Andrew Mackenzie, the company’s chair, said at the time.

Source: CNBC

Power

Oil prices rebound as traders consider Omicron’s threat to demand

(Bloomberg) –Oil rebounded from one of its biggest ever daily drops as traders assessed the risks to global demand from the Omicron variant of Covid-19 and the potential response by OPEC and its allies.

Brent rallied as much as 5.2%, climbing along with West Texas Intermediate. The World Health Organization warned the new strain could have severe consequences, while South Africa has said it appears to be more infectious, but with mild symptoms.

OPEC and its allies have already moved technical meetings in order to give themselves time to review the rout on Friday. The group is scheduled to gather later this week and decide on its output plan for January, with a pause in supply hikes on the cards, according to Morgan Stanley.

While the fundamental driver of oil’s eye-watering selloff on Friday was the emergence of Omicron, by the end of the day everything from technical selling to options markets was contriving to push the market lower. Still, analysts from Goldman Sachs to Energy Aspects said that the move was overdone and traders are now waiting to see how severe the variant’s impact will be.

“Clearly there are fears that this could have a considerable impact on demand,” said Carsten Fritsch an analyst at Commerzbank AG. “That said, Friday’s price slide was excessive.”

The Organization of Petroleum Exporting Countries and its allies will discuss the market situation and any relevant necessary steps, Russia’s Deputy Prime Minister Alexander Novak said Monday. The group postponed a ministerial meeting to get more information about current events, including the new Covid strain, he said.

OPEC will likely take a cautious stance when it gathers this week, according to Vitol Group, the world’s biggest independent oil trader. There’s also set to be more flight cancellations this week as a result of the variant, Mike Muller, the company’s head of Asia said.

Prices:

  • Brent for January settlement rose 4.1% to $75.67 a barrel at 10:33 a.m. in London.
  • Earlier on Monday, prices rose as much as 5.2% in intraday trade after ending 11.6% lower on Friday.
  • WTI for January delivery climbed 4.6% to $71.28 a barrel.

As a result of Friday’s slump, oil market volatility has blown out. One gauge of price fluctuations climbed to its highest level since May 2020. That also accompanied a surge in trading volumes as prices retreated on Friday.

The selloff wasn’t just concentrated on the front end of the oil curve either. Brent for December 2022 shed almost $8 on Friday, and had clawed back about $2.70 of that loss on Monday. The level of backwardation — a bullish structure indicating tight supply — in the futures curve also fell sharply.

“The price move was dramatic throughout the whole curve,” said Keshav Lohiya, founder of Oilytics. “Scale buying deferred Bent structure is a good risk-reward trade here as we believe backwardation is here to stay.”

Source: World oil news 

Industry News

FG insists Nigeria on track towards investment in oil, gas sector

Projected to hit $53 trillion by 2025, the global Environmental Social and Governance (ESG) assets can provide leeway for most oil and gas projects in Nigeria, especially the private and public sector, to address inherent hindrances.

Across the world, investors are now shifting attention to ESG, applying the non-financial factors as part of the key analysis process to identify material risks and growth opportunities.

A report published by Bloomberg had noted that global ESG assets are on track to exceed $53 trillion by 2025, representing more than a third of the $140.5 trillion in projected total assets under management.

Just last month, the International Energy Agency (IEA) had called for an end to fossil fuel investment as part of an attempt to ensure net-zero ambition becomes a reality by 2050. Although stakeholders in the oil and gas sector have criticised the call, it, however, sent a negative signal to the industry, which has already witnessed about a five per cent reduction in investment due to the Covid-19 pandemic.

Nigeria, with elusive governance, regulatory and fiscal outlook has over $160 billion projects yet to see Final Investment Decisions in the upstream segment.

Across Africa, the African Refiner and Distributor Association (ARDA) puts needed funds for refinery upgrade alone at $15.7 billion while an additional $7.5 billion investment, inclusive of debt, equity, and grants, will be required to build clean cooking stoves and downstream infrastructure that are going to support the attainment of the UN Sustainable Development Goals (SDGs).

Business Development experts for Vitol Services Ltd, Richard Egan, and Guillaume Quigiver, noted that ESG creates a new opportunity for African countries to generate carbon credits.

According to them, Africa has the lowest cost of generating carbon credits in the world and as such, a case should be made for a framework whereby African carbon emissions submissions are accepted in the global marketplace, stressing “ESG brings new potential revenue streams that can be incorporated into a financing package.”

Financial experts have also stated that ESG considerations are currently driving shifts in lending policies for various financial institutions and under what terms they are willing to lend, adding that while several key financial institutions like the World Bank and several Export Credit Agencies (ECAs) have pledged to end support for fossil fuel projects, Asian ECAs and some European ECAs have not made any such policy proclamations.

With the Petroleum Industry Bill (PIB) already being prepared in anticipation of presidential assent as stakeholders are divided over proper consideration for ESG, energy economist, Prof. Wunmi Iledare insisted that ESG must be on the radar of the industry as an important determinant for future investment flow.

Iledare said: “The oil and gas industry in Nigeria is not anti-environmental optimisation,” adding that the Society of Petroleum Engineers makes conscious efforts to produce oil and gas in a safe and environmentally secure manner.

According to him, for years, Health, Safety, Environment, and sustainability is a recognized discipline in the Petroleum Engineering profession.

Industry expert, Henry Adigun equally told The Guardian that although ESG is not at its best in the PIB, there are conscious efforts in the country to prioritise ESG.

He noted that the country is making efforts to attract green bonds, adding that the focus on gas would be an elixir towards ESG investment.

News Power

Operators advise government against imposing VAT on cooking gas

The Oil and Gas Service Providers Association of Nigeria, OGSPAN, has urged the Federal Government not to impose the Value Added Tax (VAT) on Liquefied Petroleum Gas (LPG), otherwise known as cooking gas.

According to OGSPAN, the planned imposition of VAT on LPG would stifle demand, utilisation, investment and growth of the sector in the country.

The National President, OGSPAN, Mazi Colman Obasi in a statement, stated: “As a stakeholder in the sector, we were delighted when the Federal Government, previously excluded operators in the LPG sector from paying the VAT.

“We were even more delighted when it declared January 1, 2021, to December 31, 2030, as ‘The Decade of Gas Development for Nigeria’ with emphasis on LPG.

“Specifically, the official launch of THE DECADE OF GAS was declared by the President of Nigeria, His Excellency Muhammadu Buhari GCFR, on Monday, 29th March 2021, also recognised 2021 as a Year of Gas.

“However, having taken these steps, we were shocked to learn that the Federal Government is currently considering imposing VAT, targeted at increasing its revenue.”

According to OGSPAN, a Presidential directive was issued July 11, 2005, to remove VAT on LPG. But the approved memo erroneously had the word “import” left on it, because at the time imports were the only source of gas.

He explained that this meant that the Federal Inland Revenue Service (FIRS) charged VAT on locally produced LPG but there was no output VAT, so the VAT cost was absorbed as a loss by industry players.

He noted that Industry operators fought for 14 years to reverse this situation and the Minister of Finance, finally removed the VAT on “domestically produced gas” under a gazette issued in 2019, thus stopping the FIRS from charging VAT on LPG under a loophole that was created in error.

“The FIRS itself under several subsequent letters advised companies that neither input nor output VAT was payable on LPG in line with other petroleum products. Industry operators and experts had warned at the time that insertion of the phrase “locally produced” in front of LPG would lead to the reverse case through this legal loophole and yet again, another round of needless quagmire.

“Experts have repeatedly pointed out that of all the petroleum products listed in that gazette, why was LPG singled out for the phrase “locally produced?” Why not gasoline, and diesel, which we don’t produce and yet import over 100 times more quantity than LPG.

“The FGN recently launched a drive for Autogas using LPG/propane. How can the gas industry grow Autogas when VAT is applied to increase gas cost but a humongous tax subsidy remains on the competing gasoline/PMS? Who is going to switch when gas prices are increasing as a result of this needless tax?’

“For too long, the LPG sector had suffered from many problems, including policy inconsistency, inadequate funding, and low domestic utilisation, which needs to be fully addressed by the current administration”, he added.

He also disclosed that the planned introduction of VAT on LPG could culminate in the reversal of gains already made in the Federal Government Gas Expansion Programme, targeted at achieving rapid development of the sector.

According to him, while a litre of government subsidised petrol, under extant price regime, actually retails for between N165 and N200 per litre, depending on different parts of the country, the average deregulated retail price per litre of LPG delivered to Abuja – FCT falls between N100/Litre for propane specification to N195/Litre for butane specification.

“The cheaper of the two, being Propane spec LPG, is the industry-approved standard for Autogas in Nigeria, which portends huge savings for families and businesses.

“Autogas use with deep market penetration with a reasonable switch from PMS and AGO will save Nigeria huge foreign exchange spend on fuel importation; expand Nigeria’s domestic energy mix with improved accessibility for LPG as a cleaner and cheaper energy source with multiple applicable uses.

“This will in great measure help the consumers especially the low-income Nigerian families with their fast-eroding purchasing power in an increasingly difficult economic environment.

“Apart from savings on the unit price per litre or kg of gas, there is also much savings on gas, with respect to engine servicing and overall maintenance cost, compared to petrol or diesel engine maintenance cost. And it is environmentally friendlier than petrol and diesel, in terms of greenhouse gas emissions”, he said.

He added: “Autogas use will help trigger the much-needed demand intensive use of gas, with the multiplier benefit effect on improved in-country production and supply sources, with the attendant reduction in gas flaring, with a marked increase in foreign direct investments in LPG production plants, trading and distribution infrastructure and equipment manufacturing in Nigeria, which has been on the decline in recent years.”

News Power

FG attracts $16.6 billion foreign investments to trade zones in 20 years

The Oil and Gas Free Trade Zones Authority has stated that it attracted $16.6bn foreign direct investment into the economy within a 20-year period spanning 2001 to 2020.

During the same period, the Authority also attracted N255.33bn local investments into the country.

The Managing Director of OGFZA, Okon Umana, disclosed this during an interview with journalists in Abuja, on Sunday.

He added that between January and May this year, OGFZA generated N9.41bn as revenue through the free trade zones.

A breakdown of the revenue revealed that N2.1bn was generated in January, while February, March, April and May had N1.45bn, N4.39bn, N1bn and N453.98m respectively.

He said this was achieved through dedicated leadership as well as the commitment and exceptional quality of members of staff of the authority.

This, he stated, had resulted in huge interests by both local and foreign investors in the zones.

The OGFZAs boss stated that currently, there were about N6.1bn investments that were expected to materialise in the Liberty Oil and Gas Free Zone.

He said: “To grow investment also means looking at the structures within our zones because as I said, you can only attract Foreign Direct Investment if you are globally competitive.

“We took a number of steps; we reviewed our standard of operation, and we came out with a timeline for delivery of our services.

“For example, in the past, we did not have a specific timeline for renewal of licence or to reissue new licences or even to process cargos.

“We came up with specific timelines – we say for example that we will take only 48 hours to clear cargos if the cargos were consigned in Free Zones.

“It will take seven days to renew the licence when all the requirements have been met and 21 days to issue a new licence under the same circumstances.”

In terms of job creation, the OGFZA boss stated that the investments have been able to unlock many direct and indirect jobs thereby empowering many Nigerians.

He said between 2005 and 2015, the authority had created 40,508 direct jobs and indirect jobs with conservative estimates at about 160,000.

He said, “These incentives are applied for activities within zones meaning that when they move items from the zone to any other place, all the taxes will be applied.”

Umana added that between 2005 and 2015, the authority created 40,508 direct jobs with indirect jobs conservatively estimated at 160,000.

Industry Production

Oando enters into settlement with Nigeria’s SEC

Oando Plc has entered into a settlement with the Securities and Exchange Commission (SEC) in the overriding interest of the shareholders of the company and the capital market after years of legal tussle.

This was contained in a circular posted on SEC’s website on Monday and obtained by the News Agency of Nigeria (NAN).

The commission in 2019 found Oando guilty of serious infractions, thereby barring Wale Tinubu, the company’s Chief Executive Officer and Mofe Boyo, its deputy CEO, from the boards of public companies for five years.

SEC also instituted an interim management to appoint new board of directors and management team for Oando.

The circular published Monday said the company had reached a settlement with the commission on the immediate withdrawal of all legal actions filed by it and all affected directors.

It said the agreement included payment of all monetary penalties stipulated in the commission’s letter of May 31, 2019; and an undertaking by the company to implement corporate governance improvements.

“Part of the terms required the submission by the company of quarterly reports on its compliance with the terms of the Settlement Agreement; the Investments and Securities Act, 2007; the SEC Rules and Regulations; the National Code of Corporate Governance and the SEC Guidelines to the Code of Corporate Governance,” it said.

“Pursuant to the powers conferred on the Commission by the Investments and Securities Act 2007, and the Rules and Regulations made pursuant thereto, the commission on July 15, entered into a settlement with Oando Plc (the company).

“The commission in its letter to the company dated May 31, 2019, gave certain directives and imposed sanctions on the company, following investigations conducted pursuant to two petitions filed with the commission in 2017.

 

Source: Premium Times

Production

Total Gabon imposes COVID vaccines on its staff to restart its paralyzed activities

For the Director General of Total Gabon,vaccination will allow his company to consider a “sustainable return to the office, … the resumption of attendance at our conviviality rooms and the holding of face-to-face meetings”.

Affected by Covid-19, Total Gabon, which plans to relaunch its activities, is putting pressure on its employees to be vaccinated against Covid-19. In a note dated June 21, 2021, the Ceo of Total Gabon, Stéphane Bassene informs his staff that all those who will not be vaccinated before September 15, 2021, will not access its oil sites. Because,”we are thus considering the end of lockdowns before accessing the sites from September 15, 2021. It is therefore imperative that all those concerned can have been vaccinated by that date,”he wrote.

To justify its decision, Total Gabon cites the difficulties caused by the containment measures imposed by oil companies on their staff before accessing an oil site. Measures that are not beneficial to the company. “Given the increasing difficulty of experiencing the confinement required of staff before accessing industrial sites, its very high cost and the disruptions that this causes in the rhythms of work, it is now more than necessary to return to normal operation from 15 September. In addition, the vaccination of as many people as possible will make it possible to lift the periods of confinement currently required to go on site and which are felt by our colleagues and partners to be very trying,”says Stéphane Bassene.

Within the company, this decision is difficult to pass on to employees in the oil sector. This is all the more true since in Gabon vaccination is not compulsory. “Until proven otherwise, Total Gabon is not the Gabonese State and cannot impose on Gabonese citizens what the State has not declared mandatory by laws or regulations. This decision is absurd, implausible, unacceptable,” saidSylvain Mayabi Binet, secretary general of the National Organization of Petroleum Employees (Onep).

General strike in prospect

To find out if Total Gabon had the government’s agreement, Sylvain Mayabi Binet questioned the Minister of Petroleum, Vincent de Paul Massassa, on July 12, during the program “Face à vous” on Gabon 1st. The member of the governmentsaid that he did not have that information. “It is you who are communicating it to me at this moment”. Nevertheless, the minister encouraged Gabonese to get vaccinated and reminded them that to date, vaccination remains the best way to protect themselves against the pandemic.

But Onep, the most representative union of the oilsector in Gabon, says it is ready”to call workers to a general strike in the sector if the individual freedoms guaranteed and protected by the country’s constitution are violated by Total Gabon. Because if it goes to Total Gabon, it will inevitably spread throughout the oil sector,” says Sylvain Mayabi Binet.

When contacted, Total Gabon has not yet reacted. During 2020, Total Gabon recorded a 46% decrease in revenue compared to the previous year, and a net profit down 274%.

 

Source: Agence Ecofin

News

Nigeria’s oil output drops 11.47% to 1.343mbpd in Q2 – OPEC

Nigeria’s oil output dropped by 11.47 per cent year-on-year, YoY, in the second quarter of 2021 (Q2’21).

But the decline also showed significant under-production against the quota, Organisation of Petroleum Exporting Countries, (OPEC) data have shown.

In its July 2021 Monthly Oil Market Report (MOMR), obtained by LEADERSHIP, OPEC disclosed that on the average, the nation produced 1.343 million barrels per day in Q2’21 compared to 1.517 mb/d produced in Q2’20. This also compares negatively with the OPEC quota of 1.4 mb/d.

Specifically, the report has it that the country produced 1.372 mb/d, 1.344 mb/d and 1.313 mb/d, in April, May and June, 2021 respectively, compared to 1.705 mb/d, 1.436 mb/d and 1.411 mb/d, produced in the corresponding months of 2020.

At the Q2’21 average output the country requires about 500 mb/d output of condensate to meet its 2021 budgetary target of 1.8 mb/d. But currently the estimated condensate output is put at 400 mb/d, indicating a likely significant shortfall.

However, the shortfall may not affect revenue estimates since the 2021 oil revenue was based on oil price of $40 per barrel, while actual price in recent weeks have hovered above $70 per barrel.

Meanwhile the OPEC report, which painted a bright prospect for the oil market in the remaining part of 2021, stated: “World oil demand growth in 2021 is forecast at 6.0 mb/d, unchanged from last month’s assessment, although there have been some regional revisions. Total oil demand is projected to average 96.6 mb/d.

“The Q1’21 was revised lower, amid slower than anticipated demand in the main Organisation for Economic Co-operation and Development (OECD), OECD consuming countries. This was counter-balanced by better-than-expected data from OECD Americas in Q2’21, which is now projected to last through the Q3’21.

“Solid expectations exist for global economic growth in 2022. These include improved containment of COVID-19, particularly in emerging and developing countries, which are forecast to spur oil demand to reach pre-pandemic levels in 2022.”

Meanwhile, Nigeria’s crude oil exports fell by a whopping 41.9 per cent year-on-year in the first quarter of 2021. This is according to data contained in the Central Bank of Nigeria’s balance of payment report.

Nigeria received in its current account, crude oil and gas export proceeds of $6.48 billion in the first quarter of 2021 compared to $11.1 billion in the corresponding period in 2020. It also represents a 16.4 per cent drop when compared to the $7.7 billion recorded in the 4th quarter of 2020.

Crude oil and gas export proceeds of $54.5 billion in 2019 made up about 84 per cent of the government’s export earnings. However, crude oil and gas exports declined to $31.4 billion in 2020 as Covid-19 pandemic triggered a global economic lockdown crashing oil prices to below zero in the second quarter of 2020.

OPEC member countries have had to endure year-long collective crude oil cuts to help limit supplies, shoring up prices. While this has contributed to the stabilisation of oil prices, member countries have seen their revenues plummet as they cannot push out as much volumes as they would have preferred.

Nigeria is currently pegged to an export volume of about 1.4 million barrels per day, remarkably less than the 1.8 million barrels per day production volume that it has averaged over the years and a far cry from its 2.5 million barrels per day production capacity.

According to a presentation on the 2021 budget performance by Nigeria’s minister of finance, Dr Zainab Ahmed, Nigeria has abided by the OPEC+ cut despite this production capacity.

However, crude oil production is projected to increase to 1.86 million barrels per day in 2021, as economies recover from the recession, and moderated by OPEC+ quota agreements, as stated by the minister of finance.

It is worth noting that, apart from the decline in Nigeria’s crude oil production, earnings were also affected by the inability of India to buy as much crude from Nigeria.

 

Source: Leadership

Factory Production

Sahara Energy backs Fujairah to emerge as global trading hub

Speaking ahead of the upcoming virtual 12th International Fujairah Bunkering & Fuel Oil Forum (FUJCON 2021) in the United Arab Emirate (UAE), Laven said ongoing transformative projects would give traction to the drive to develop Fujairah “as a global trading hub will also support the growth in demand as activity levels continue to increase.”

“The bunker market during 2020 has had to deal with a number of challenges. At the beginning of the year, we had the IMO 2020 specification change, then following the COVID-19 pandemic, global demand and bunker markets around the world have been impacted in different ways. Hopefully, 2021 will see a return to normality and Fujairah can see growth,” he added.

Launched in 1978 and fully operational in 1983, the Port of Fujairah is the second-largest bunkering hub in the world after Singapore. It offers general cargo, bulk cargo, wet bulk cargo, and container services. The port has a vast oil storage capacity of 10 million cubic meters with plans to enhance productivity through the extension of the storage capacity to 42 million barrels of crude oil.

He asserted that as a leading player in the UAE oil and gas sector, Sahara Energy would continue to promote investment projects aimed at ensuring the availability of clean fuels.

“Sustaining strategic and transparent conversations around the future of the energy sector requires the commitment and collaboration of all stakeholders. Sahara Energy and its parent organization, Sahara Group are delighted to lend its voice to shaping the future that will best serve global well-being.”

Laven who will be speaking on Risk Management and Oil Storage alongside other speakers said the issue of price remained critical to risk management considerations in oil and gas transactions. “But the strategy of investing in flat price without managing the price risk carries a significant amount of risk. When investing in oil, a combination of appropriate risk management and trading market structure and arbitrage can still generate material returns,” he said.

the availability of locally produced fuels, enhanced automation, and access to clean fuels should provide a level of market confidence in supply at the Port of Fujairah, Andrew Laven, Chief Operating Officer, Sahara Energy Resources DMCC, Dubai has said.

“The bunker market during 2020 has had to deal with a number of challenges. At the beginning of the year, we had the IMO 2020 specification change, then following the COVID-19 pandemic, global demand and bunker markets around the world have been impacted in different ways. Hopefully, 2021 will see a return to normality and Fujairah can see growth,” he added.

Launched in 1978 and fully operational in 1983, the Port of Fujairah is the second-largest bunkering hub in the world after Singapore. It offers general cargo, bulk cargo, wet bulk cargo, and container services. The port has a vast oil storage capacity of 10 million cubic meters with plans to enhance productivity through the extension of the storage capacity to 42 million barrels of crude oil.

He asserted that as a leading player in the UAE oil and gas sector, Sahara Energy would continue to promote investment projects aimed at ensuring the availability of clean fuels.

“Sustaining strategic and transparent conversations around the future of the energy sector requires the commitment and collaboration of all stakeholders. Sahara Energy and its parent organization, Sahara Group are delighted to lend its voice to shaping the future that will best serve global well-being.”

Laven who will be speaking on Risk Management and Oil Storage alongside other speakers said the issue of price remained critical to risk management considerations in oil and gas transactions. “But the strategy of investing in flat price without managing the price risk carries a significant amount of risk. When investing in oil, a combination of appropriate risk management and trading market structure and arbitrage can still generate material returns,” he said.

Production

Ikike oil field likely to commence operations by year end

Oil major, Total has announced an immediate plan to launch operational activities around its Ikike field, offshore Nigeria, by the end of 2021.

Indeed, the oil firm, in its yearly filing with the US Securities and Exchange Commission (SEC), stated that it expects to start up its Ikike field by the end of 2021 and will drill a number of exploration wells across its African portfolio.

The French company took a final investment decision (FID) on Nigeria’s Ikike project in January 2019 and hopes to reach its first oil late this year.

The company had hoped to begin production at the project in 2020. The field will be tied back to the existing Amenam field.

Total singled out two potential projects in Nigeria. The authorities approved a field development plan for Preowei in 2019.

The company is also considering work on the Owowo discovery, which is found in 2012.

Total began drilling an appraisal well on Block 20/11 in January and another is planned for Block 48 this year. It bought the former block in June 2020, following the collapse of Cobalt International Energy, which had made a number of discoveries.

On Angola’s Block 17, Total and the local authorities reached a deal to extend the license until 2045.

Total agreed to drill two exploration wells on the block in 2022-23, adding that it is also working to maintain production from the block and will drill infill production wells this year, which will also begin producing this year. Further out, it is also working on three brownfield projects.

These are Zinia Phase 2, CLOV Phase 2, and Dalia Phase 3 – will begin producing in 2022, it said. It had previously expected to start these in 2020-2021.

Total paid $2.96 billion in taxes in sub-Saharan Africa, of which $1.09bn was paid on Block 17 to the Angolan government.

The French company paused work on Block 0 in April 2020, because of the pandemic. It expects to resume this in 2021.

Meanwhile, in Namibia, Total is planning to drill the Venus well this year, on Block 2913B. The company did not commit to a particular time, but various sources have predicted the third quarter.

Under the Ugandan development plans, the companies will drill around 430 onshore wells and build two crude processing facilities.

Tilenga will require 400 wells, half of which will be water injection, and is expected to produce 190,000 barrels per day. Kingfisher, which is 150 km to the south of Tilenga, will involve 31 wells and produce 40,000 bpd.

Uganda, Tanzania, and Total planned to sign a deal on March 22. However, they pushed this back into April.

The Uganda plan took top billing for the company, with Total saying it would “focus its investments primarily” on the EACOP and Tilenga projects. Other plans named by the company were all post-FID.

The Tilenga, Kingfisher, and EACOP projects will produce oil with 13 kg of CO2 per barrel, ahead of the industry average of 20 kg. As such, Total defended its investment in the project, saying this was in line with its climate ambition plans set out in May 2020.

Angola is at the heart of Total’s production, with an output of 184,000 BPD in 2020, down from 205,000 BPD in 2019. Africa’s reserves contribution to the company was all down last year.