Author: admin

The energy revolution, accelerated by the pandemic, is changing the DNA of the oil and gas industry at its core.

In a recent interview Glynn Williams, CEO of Silixa — a company that provides fiber optic-powered data solutions for the oil and gas sector (as well as several others) — reveals something of the emerging recognition that the oil and gas industry can make a strong contribution to the renewables sector:

“Many people and entire states depend on the prosperity and well-being of independent oil and gas companies (IOCs) and their suppliers, but they are still being cast unfairly as the villains of climate change and the renewables revolution. In reality, they have been fully engaged in the huge undertaking of transitioning their businesses and practices toward the renewables sector. So, far from being its enemies, they are increasingly its facilitators.”

What is your view on the current state of the oil and gas market in the wake of a pandemic and what are the prospects for the future?

We are currently seeing a big bounce-back in activity despite continued disruption being foreseen for the remainder of the year. Moreover, in the medium term the fundamentals look strong with pre-pandemic demand levels returning at the end of 2022. There has been significant underinvestment during the COVID period and that will, I feel, lead to a return of increased spending in 2022.

For us, oil and gas will remain an attractive segment in which to operate as our customers in the OPEC Middle East, the big water offshore and the U.S. shale sectors will all make improved levels of investment, which will then lead to further opportunities for Silixa.

Other opportunities will arise out of operators’ need to meet their ESG requirements. A feature we have seen this year has been reducing scope-one emissions.

We have recently launched an intervention system with the time in the well acquiring data significantly reduced to a matter of hours versus conventional techniques. So, our scope-one emissions are reduced because we don’t require generating plants at surface operations for days but only hours at a time. If we are dealing with issues of fugitive emissions through well integrity problems, they can be quickly resolved by identifying the source of the leak, enabling the customer to do their mediation quickly.

What we are also seeing is an acceleration of digitalization allowing, for example, supervision of well-side operations without the need to fly specialists around the world. The advance of digital technology and solutions established during the pandemic will be a strong platform for growth for some of the faster-moving service providers.

How much does public image reflect the actual direction of travel of IOCs and their suppliers?

Although oil & gas companies and their suppliers are branding themselves as green through mission statements, logos and corporate color choices, rebranding can be pointless where it doesn’t express and underline real commitment.

However, oil & gas company branding increasingly reflects fundamental changes in philosophy and business practices. For example, BP has repositioned with solid renewable energy targets and a defined roadmap to decarbonization. Another example is Total, which has undergone a complete rebranding becoming TotalEnergies, highlighting the company as a broad energy supplier rather than just oil and gas.

In many ways IOCs have embraced the energy transition, and companies like ExxonMobil have identified multiple carbon capture usage (CCU) projects. Some may have been slow in adopting energy transition, but are now accelerating the dialogue, making very strong commitments to carbon capture and storage hubs.

This year we have noticed a greater sense of purpose among the major IOCs, reflecting a response to shareholder pressures and what’s happening in the wider world.

Decarbonization, renewables and transferable skills

Investment that was going into exploration work previously is now going into renewables markets, largely by acquiring licenses and the transition from off-shore gas to off-shore wind, but mainly in operating in new areas. Some large companies have been paying premiums to access renewables markets, I hope it works out for them.

How to access the subsurface is very well known in the oil & gas industries: how to drill wells, how to make sure they are secure, how to monitor them. All of that is very transferable into CO2 capture and storage. The offshore wind energy sector will be able to exploit the practices of the technologies and competencies of the subsea providers.

However, it will be challenging for those in the offshore supply sector who are offering generic products because there will be fewer wells completed and progressively less intervention over time. So some of the generic providers will struggle if they don’t have anything that stands out and is considered best-in-class.

As for Silixa, we are well-positioned. Roughly half of our sales are now being generated outside of oil & gas. We are finding that our oil & gas solutions are now being rapidly adopted for use in mining, carbon capture & storage and geothermal sectors with little investment or actuation on our part. So I am very optimistic about what is playing out in new areas.

How does Silixa fit into the new energy normal?

It has been a broadly-based business for some while. Some identify with us as an oil & gas services business, but we have a lot of relationships outside that with a very broad offering. We are fortunate in having a multi-disciplinary team that already speaks the language of the emerging sectors.

We have five business units, three of them facing oil & gas and two of which are facing respectively mining and the broader area of environmental infrastructure. Within those, we have an alternative energy group, and an earth science group addressing the emerging pressures on the world, such as climate change and increasing populations. 

Our knowledge of the subsurface domain will be key to the safe and economic storage of CO2 and success of complex geothermal systems. This understanding of the subsurface domain and application of the technology over many years has resulted in all parts of our business well populated with experienced geophysicists and geotechnical staff.

A case in point relating to our carbon storage and geothermal knowledge and transferable technologies is in the company’s optically distributed fiber optic sensing. This is unique in that the technology can make measurements of what we call the far-field, which enables it to track the movements of fluids within the system and in the near-field. This enables us to understand when the system is in optimum conditions.

Can you give any specific examples of transference in this area?

Transferable technology, like people’s transferable skills, can be applied quickly and appropriately. One of the successes that gives us confidence looking forward is the success we have already enjoyed in transferring some of our oil and gas flow metering solutions to the mining sector where we can help our customers understand flow and movement within large networks and help achieve their ESG objectives avoiding water and energy use.

As a result of considerable early success, we are making a significant investment in building an international team as we believe our proven technologies will assist in overcoming ESG and technical challenges in the provision of base metals such as copper and nickel, which are vital in the energy transition picture. So, there are many elements to our technology that are very special, particularly our ability to quickly apply proven techniques to the challenges of energy transition that are now so urgently needed to combat global warming.

Forbes by Robert Rapier, December 24, 2021

The U.S. government has authorized Petroleos Mexicanos’ bid to take over Royal Dutch Shell Plc’s Deer Park refinery, according to Mexico President Andres Manuel Lopez Obrador.

It’s something historic,” the president, broadly known as AMLO, told reporters Wednesday.

Pemex has been awaiting approval from the U.S. Treasury Department to acquire Shell’s stake in the Texas plant, a move that would expand its refining capacity and secure critical fuel supplies for the state oil producer. The purchase comes as AMLO seeks to increase state control of the country’s energy markets, refine all of its own oil, and reverse more than a decade of production declines.

A Treasury Department representative declined to comment.

The acquisition will cost $1.2 billion, AMLO said at a press conference, more than twice the price the company announced in May. Pemex will pay off the refinery’s debt to complete the purchase, tapping Mexico’s National Infrastructure Fund, Pemex Chief Executive Officer Octavio Romero said Wednesday.

Bloomberg previously reported that Pemex could spend about $1.6 billion on the takeover, using the infrastructure fund and a bridge loan from commercial banks to pay off the refinery’s debts, a part of the deal that wasn’t clear when it was first announced.

Pemex Refinery Deal May Cost $1 Billion More Than Announced

Pemex is making the acquisition even as its finances are so dismal the government is injecting billions of dollars into the company as debt has soared to $113 billion, the most of any oil company in the world.

Mexico’s Foreign Affairs Minister Marcelo Ebrard said the Committee on Foreign Investment in the United States approved the sale in a letter. There were no pending issues of national security, and the review of the sale was concluded, Ebrard said, citing the letter.

CFIUS is responsible for reviewing sales of critical U.S. infrastructure to foreign buyers for national security.

Shell previously said the deal was expected to close early next year, subject to regulatory approvals.

The sale has sparked controversy, with critics claiming that it could affect national energy security in the U.S., due to rising gasoline costs and concerns that Pemex lacks the funds and expertise to run a U.S. refinery.

Last week, two New York businessmen filed a lawsuit in a U.S. District Court in Houston, alleging that the sale would increase gasoline prices and impact their business’s energy costs. In June, U.S. Representative Brian Babin published a letter to CFIUS opposing the deal because he claimed that Pemex didn’t have a record of operating refineries to international standards.

Pemex owns and operates six refineries in Mexico, but due to a lack of investment they are operating at less than half of their capacity, and Mexico imports almost 80% of the gasoline consumed in the country. Pemex is also constructing a new, 240,000-barrel-a-day refinery in AMLO’s home state of Tabasco that has gone over budget after the government’s initial estimate of $8 billion.

Bloomberg by Amy Stillman, December 23, 2021

President Joe Biden’s energy chief extended an olive branch to the oil industry Tuesday, telling executives a crude export ban is not under consideration, while assuring them that the administration was “not a bogeyman.”

Energy Secretary Jennifer Granholm made the virtual remarks Tuesday to an outside advisory group with members including executives from such companies as Exxon Mobil Corp. and Royal Dutch Shell Plc. Her conciliatory tone comes as the administration’s policies on energy production, which included a temporary halt to oil leasing on federal lands and the termination of a permit for the Keystone XL pipeline, have drawn the ire of industry. 

“I do not want to fight with any of you,” Granholm told the National Petroleum Council. “I do think it’s much more productive to work together on future facing solutions.” 

The administration, Granholm said, is not considering reinstating a ban on the export of crude oil — a tool the Biden White House had previously been considering as it sought ways to address gasoline prices that hovered around a seven-year high, setting off political alarm bells.

Granholm’s comments represent the administration’s most definitive statement regarding the export ban, which had the potential to upend oil markets while discouraging domestic oil production.

“I heard you loud and clear and so has the White House,” Granholm said in her remarks. “We wanted to put that rumor to rest.” 

Granholm’s address to the council follows finger pointing over the issue of high gasoline and oil prices. The industry was also angry with the administration’s decision to dramatically reduce access to oil and gas development, followed by complaints domestic producers weren’t ramping up production amid increasing energy demand as the worst of the pandemic ended. 

The Biden administration has since sold oil and gas drilling rights in the Gulf of Mexico after a federal district judge in June ruled against the moratorium. 

Granholm, in her comments, asked the industry to ramp up oil and gas production, while repeating previous complaints about unused permits and leases. 

“While I understand you may disagree with some of our policies, it doesn’t mean the Biden administration is standing in the way of your efforts to help meet current demand,” Granholm said, while asking the industry to help partner in the administration’s battle against climate change. “I firmly believe those that embrace the change rather than fighting it will be rewarded on the other side.”

Bloomberg by Ari Natter, December 21, 2021

Market levels are expected to remain at current levels, with medium sour grades seeing support from the heightened pace of buying. Crude oil eased early in the week as traders weighed the potential near-term oil demand impacts of rising coronavirus cases around the world amid concerns about the effectiveness of vaccines against its omicron variant that weighed on market sentiment.

The World Health Organization said omicron poses a very high global risk. A strengthening in the US dollar also weighed on oil prices. Pfizer and BioNTech pharmaceutical companies said preliminary laboratory studies demonstrate that three doses of the Pfizer-BioNTech COVID-19 vaccine neutralize the omicron variant while two doses show indications of a significant increase in protection.

Crude oil prices averaged about 2 percent higher, despite persistent market volatility and an uncertain demand outlook amid concerns about omicron. Going forward, the market structure will depend heavily on the demand part of the equation, while a weaker oil market structure will probably weigh on market sentiment in the near term.

China’s announcement that it would cap overall emissions rather than restrict energy consumption to meet its climate goals could be a positive boost to the oil market.

However, oil prices came under further pressure after the International Energy Agency showed lower global oil demand growth forecasts for 2021 and 2022. Crude oil prices settled slightly higher, reversing earlier losses after the EIA’s weekly data showed the largest US crude draw last week since September, exceeding market expectation. Oil prices were supported with higher equity markets, as investors weighed the US Fed’s decision to tighten monetary policy to slow rising inflation.

While crude production growth outside of the OPEC+ remained just 90,000 barrels per day, industry reports suggest the figure to rise to 1.5 million bpd in 2022 and 0.9 million bpd in 2023. The reports said most growth will come from the US and its Strategic Petroleum Reserve release could add an additional 400,000 bpd to the global oil supply pool.

The IEA’s latest market outlook had a more bearish outlook for global oil balances in the first half of 2022. It now sees a surplus of 1.7 million bpd materializing in the first quarter of 2022 and a surplus of 2 million bpd in the second quarter of 2022.

December and January balances could tighten further as a major pipeline outage in Ecuador has forced crude production shut-ins which we estimate will take about 120,000 bpd of supply off the market on average in December and could potentially negatively impact January output too. Moreover, Russia’s crude and condensate production growth has slowed down recently because the country is running out of spare production capacity.

However, from January 2022, global crude balances are expected to be in surplus.

On the other hand, global prices of liquefied natural gas are trading at record highs. Prices will only fall from spring if Nord Stream 2 is commissioned but the world must get ready for another bumpy year ahead.

ArabNews by Mohammed Al-Shatti, December 20, 2021

France’s TotalEnergies (TTEF.PA), Royal Dutch Shell (RDSa.L), Malaysia’s Petronas and Qatar Energy on Friday scooped up big offshore fields in Brazil together with state-owned Petrobras, paying nearly $2 billion to its cash-strapped government.

While TotalEnergies (28%), Qatar Energy (21%) and Petronas (21%) made the top offer for Sepia field, Petrobras, formally Petroleo Brasileiro SA (PETR4.SA), later entered the consortium by exercising preference rights to take a 30% stake.

Petrobras (52.5%), Shell (25%) and Total (22.5%) secured the nearby Atapu field.

Officials, who had been keen to attract major foreign players, deemed the auction a success, and analysts said the offers agreed to were relatively rich.

The selloff was widely seen as a test of Brazil’s investment climate and of large oil producers’ willingness to keep spending big on traditional oil assets, despite increasing pressure over climate change and toward energy transition.

TotalEnergies, which snapped up a stake in both blocks, said the investment will bring output with “costs well below $20 per barrel of oil equivalent” and with carbon emissions rates below industry levels.

“These are unique opportunities to access giant low-cost and low emissions oil reserves,” CEO Patrick Pouyanné said in a statement.

Signing bonuses were fixed in reais at the equivalent of $1.3 billion for Sepia and $740,000 for Atapu. Companies bid for a percentage of the production they were willing to share with the government, winning the highest: 37.43% for Sepia and 31.68% for Atapu.

Petrobras, TotalEergies and Shell shares fell on Friday, following a 2.60% decrease in Brent prices.

Brazil attempted to auction both fields in 2019, but neither received offers, even from Petrobras. At the time, complex legal issues and rich signing bonuses kept oil majors away.

This time, the bidding terms were considered more attractive, several industry sources told Reuters, largely due to big cuts in both signing bonuses and minimum profit oil.

Government moves to streamline rules and lower fees “drew bids well above the minimums for both assets,” said Andre Fangundes, vice president of consultancy Welligence.

“Companies were more aggressive than we expected,” said Marcelo de Assis, head of Latin America upstream research at Wood Mackenzie.

Eleven companies signed up for the chance to bid on Friday. Exxon Mobil Corp (XOM.N)made final arrangements to bid together with Petrobras and a subsidiary of Portugal’s Galp Energia SGPS SA (GALP.LS), people close to the negotiations said, but never presented a final offer.

Oil majors will be able to add production to their portfolios in the short term. Petrobras is ramping up production at Sepia to 180,000 bpd and has reached the 160,000 bpd maximum capacity at Atapu. A second platform is planned for each field.

Cementing Brazil’s status as Latin Americas biggest oil producer, the two fields could boost the country’s production by 12% over the next six years, adding 700,000 bpd, and bringing in almost $40 billion in investment, its energy ministry said after the auction. Petrobras is set to receive $6.2 billion for past investments in the two fields.

Reuters by Gram Slattery, December 20, 2021

Oil supermajor Shell is facing some big changes in its future as stakeholders approve the long-talked-about move from the Netherlands to the U.K. This follows months of controversy over its scheduled North Sea Cambo oilfield project, resulting in Shell’s withdrawal from the development, and its huge drive to invest in renewables over the next decade. These are just a few of the major shifts in Shell’s energy strategy that suggest the company will undergo a substantial transition in the coming years. 

Last week, 99.8 percent of Royal Dutch Shell stakeholders approved the company’s move to London, which it hopes will help simplify its dual tax structure and make it more competitive. This could lead to a transformation like that seen by Total’s name change to TotalEnergies earlier this year, as Shell drops the ‘Royal Dutch’ to become Shell PLC.

The move is likely linked to a legal case loss earlier in 2021 when a Dutch court ruled that Shell must decrease its carbon emissions by 45 percent by 2030, in line with national aims to decarbonize the economy. Shell has already announced a net-zero carbon emissions target for 2050 and aims to reduce its emissions by 45 percent by 2035, five years behind the ruling. 

But Shell insists that the move will merely simplify its complicated dual-class share system, currently incorporated in the U.K. but with Dutch tax residence. Nick Stansbury, head of climate solutions at Legal and General Investment Management, a major Shell shareholder, explains, “We think this is actually a relatively routine bit of corporate simplification, a kind of corporate tidying up exercise to deal with a complex bit of historical legacy that is simply no longer needed in the world that Shell now lives and operates in.”

Shell stocks have dropped slightly since the announcement, from $44.14 on Friday 10th December to $42.83 the following Wednesday. However, uncertainty around the latest wave of Covid-19 infections and the worldwide implementation of greater restrictions have hit several oil and gas stocks hard in recent weeks. Shell believes the move will ultimately be positive for its stakeholders, as well as for its planned projects in both fossil fuels and renewables. 

Shell’s Chair, Sir Andrew Mackenzie stated of the proposal last month, “The simplification will normalize our share structure under the tax and legal jurisdictions of a single country and make us more competitive. As a result, Shell will be better positioned to seize opportunities and play a leading role in the energy transition.”

The company has already promised major changes to its portfolio following the dip in oil and gas demand during the pandemic, as well as in response to international pressure to decarbonize operations. Much like other oil majors, Shell is doubling down on its investments in renewables, earmarking between $5 and $6 billion a year for green energy. Representatives have previously stated that oil production most likely peaked in 2019 and now is the time to get ahead of the game when it comes to alternative energy development. 

Its objective is to sell around 560 terawatt-hours annually by 2030, twice its current electricity sales. Building upon its current hydrogen operations, Shell hopes to develop integrated hydrogen hubs to serve both industry and heavy-duty transportation, expecting to achieve a double-digit share of the world’s clean energy sales. 

In the mid-term, Shell announced a $565 million investment for renewable energy projects in Brazil through 2025, earlier this year. Developments include largescale solar fields and a natural gas-fired thermal plant, which could start generating energy as early as 2022. 

However, the oil major was repeatedly criticized this year for its ongoing interest in the development of the Cambo oilfield in the North Sea, particularly following the COP26 climate summit that took place in Glasgow this November. Until this December, Shell was pursuing the further exploration and development of Cambo, seemingly contradicting its pledge to move away from fossil fuels and decarbonize operations. But following mounting public pressure, Shell ultimately withdrew from the Cambo oilfield development last week, forcing Siccar Point Energy to put the project on hold. 

Siccar Point’s CEO, Jonathan Roger, expressed disappointment in Shell’s decision to exit the project. He still believes that “Cambo is a robust project that can play an important part of the UK’s energy security, providing homegrown energy supply and reducing carbon-intensive imports, whilst supporting a just transition.”

So, the jury is out on how dedicated Shell is to reducing its carbon emissions by 45 percent by 2030, as ruled in the Netherlands earlier this year, especially following its recent decision to move to the U.K. However, its recent withdrawal from Cambo, as well as a significant increase in its renewable energy investments over the last year, suggest that Shell is open to diversifying its portfolio, as it aims to get ahead of the competition in several green energy areas.

OilPrice by Felicity Bradstock, December 17, 2021

Brent prices and particularly calendar spreads are being hammered by the rising number of confirmed coronavirus cases around the world, which is threatening tougher international travel restrictions and renewed domestic lockdowns.

Brent spreads have slumped since the start of November, roughly two weeks after the seven-day average new case count started rising in the middle of October, according to global statistics compiled by Our World in Data.

There has been an inverse correlation between the two since the start of the year, as the ebb and flow of infections produces a relaxation and tightening of quarantines and other restrictions impacting oil consumption.

Brent’s calendar spread between futures contracts for February and March 2022 has slumped to a backwardation of just over 20 cents per barrel, down from a peak of more than $1.20 at the start of November.

The seven-day average number of new confirmed cases around the world has climbed to almost 620,000 per day from just 400,000 in the middle of October.

The new wave of infections is likely being driven by a combination of seasonal factors (respiratory diseases spread more rapidly in the northern hemisphere winter) and the emergence of the more transmissible Omicron variant.

The seasonal increase was widely anticipated by policymakers and traders, but the scale and suddenness was not, prompting an abrupt tightening of quarantines and social-distancing controls.

TIDE OF ANXIETY

Previous waves of new coronavirus infections in February-April and June-August also produced a softening of Brent calendar spreads.

But the most recent wave has coincided with growing concerns about rising inflation, the health of the global economy and the outlook for oil consumption in 2022.

And the earlier oil price rise between August and October has triggered a belated release of emergency reserves, led by the United States, adding to supply in the next few months.

The result has been a huge swing in spreads, accelerated and amplified by liquidation of a large number of hedge fund positions, most of them concentrated in nearby futures contracts.

If coronavirus behaves like other respiratory infections, the number of new cases is likely to continue rising for at least another month, though social distancing, health regulations and vaccinations may blunt the increase.

While new cases are accelerating, pressure for greater restrictions on the number of social contacts and cross-border movements will continue to weigh on forecasts for oil consumption.

Brent prices and calendar spreads are therefore likely to remain under pressure until there are clearer signs the new wave is being brought under control by some combination of controls, the arrival of spring weather, or growing acquired immunity in the first quarter of next year.

Reuters by David Evans, December 17, 2021

Recovering economies this year have resulted in a robust rebound in oil demand, disproving some projections from the onset of the pandemic in 2020 that the world had already seen peak oil demand.

Despite scares of new variants, such as Delta and lately, Omicron, global oil demand is on track to reach pre-pandemic levels within months and to further rise in coming years. Peak oil demand is not in the cards in the near future, analysts say.  

Oil investors surveyed by Bloomberg Intelligence in November have also significantly recalibrated their expectations of peak oil demand over the past two years.  

Two and a half years ago, a fifth of oil investor clients polled by Bloomberg Intelligence said that oil demand would peak by February 2021, BloombergNEF’s Chief Content Officer Nathaniel Bullard notes. In June 2019, another one-third of oil investors thought we would see global oil demand peak by 2025. In previous surveys, most investors expected peak oil demand by 2030. 

But the latest survey from last month showed a stark difference in the general timeline to peak oil demand compared to the previous four polls.

Currently, just 2 percent of oil investors believe peak oil demand will occur by 2025, and fewer than 40 percent see that peak before 2030. One-third of investors expect oil demand to peak between 2025 and 2030, but another one-third think that peak would be after 2030, at some point between 2030 and 2035.  

Mid-2030s is currently OPEC’s timeline for peak oil demand. Global oil demand is expected to continue to grow into the mid-2030s to 108 million barrels per day (bpd), after which it is set to plateau until 2045, OPEC said in its 2021 World Oil Outlook (WOO) earlier this year. OPEC sees oil demand growing “strongly” in the short- and medium-term before demand plateaus in the long term. 

Despite expected plateauing demand in the long run, oil will continue to be the fuel with the single largest share of the global energy mix by 2045, meeting 28 percent of energy demand then, OPEC Secretary General Mohammad Barkindo said last month, stressing the need for investments in oil supply to meet consumption. 

Demand is set to grow, as the world still runs on fossil fuels which account for around 85 percent of total global energy demand. 

The most meaningful dent to oil demand is likely to come from electric vehicles (EVs), which, in some countries, have started to eat away at oil demand for road transportation. 

Nevertheless, it will take years to see road fuel demand globally severely impacted by electrification in transportation. 

According to BloombergNEF’s Electric Vehicle Outlook 2021, EVs of all types are already displacing well over 1 million barrels of oil demand per day. In its Economic Transition Scenario, BloombergNEF sees oil demand from road transport overall peaking in 2027 and then declines steadily from there.  

EVs have the potential to displace some oil demand, but the world as a whole is not there yet, other analysts say. 

“When the impact of the pandemic on world oil markets was at its height, there was talk that we had already passed the point of “peak demand”, and consumption would never again be higher than it was in 2019. Wood Mackenzie analysts did not believe it at the time, and their scepticism is being vindicated,” Ed Crooks, Vice-Chair, Americas at Wood Mackenzie, wrote in October. 

“Peak demand will come only through long-term structural changes, most immediately in light road transport, and those take time. There are signs that the surge in EV sales in Europe may be starting to chip away at road fuel demand there, but most of the world is not there yet. As the impact of the pandemic continues to fade, that is likely to become increasingly apparent,” Crooks noted. 

OilPrice by Tsvetana Paraskova, December 15, 2021