Investors challenge ExxonMobil on multiple fronts

  • Spanish Market: Crude oil, Natural gas
  • 04/01/21

ExxonMobil is facing a three pronged attack from activist investors hoping to force the US major to radically change how it spends its cash.

Investment firm Engine No 1, with the backing of the California state teachers' pension fund, wants ExxonMobil to add fresh blood to its board. The New York State pension fund is threatening to divest its stake in the company unless it moves away from fossil fuels more quickly. And the hedge fund DE Shaw wants ExxonMobil to cut costs, including capital spending, to protect its dividend.

ExxonMobil's investor challenges go to the heart of an issue faced by oil and gas industry producers as a whole: how to use its still formidable financial resources to transition toward a cleaner energy future or whether to hunker down, focus on its core business and just return cash to shareholders.

Majors have successfully fended off activist challenges before. But two factors that might help the investors this time around are the demand-slashing impact of Covid-19 and a broadening embrace of the threats of climate change in most markets. The pandemic has sapped global energy demand and significantly weakened prices, forcing producers to preserve cash flow as institutional and retail investors flee the sector. It has also laid bare the oil and gas industry's poor-to-mixed record addressing climate issues, leading many to speed up efforts to lower emissions.

Lots of capex, not enough return

While spending was cut in 2020 in response to the pandemic, ExxonMobil argues that the industry must return to higher capex spending soon in order to produce enough energy for the world's growing population.

"If the industry is to meet credible third-party estimates for energy demand, we will need to significantly increase investments," chief financial officer Andrew Swiger said during the third quarter earnings call with analysts.

But activist investors argue that even before Covid-19 the company squandered billions of dollars in capital investments over the years without sufficient returns to show for it.

In the first decade of the 21st century, ExxonMobil generated an average return of 35pc per year from its upstream capital projects. But annual returns in recent years have plummeted to less than 6pc. From 2015-2019, in the US alone, the company generated less than a 1pc return in three of those five years despite spending an average of nearly $7bn a year, according to company reports.

"We believe ExxonMobil's underperformance can be largely attributed to its pursuit of production growth at the expense of returns and a lack of adaptability to changing industry dynamics, including higher production costs and growing long-term demand uncertainty," according to a 7 December letter Engine No 1 sent to ExxonMobil's board of directors.

Engine No 1, which bought a $40mn stake in ExxonMobil, is partnering with the California State Teachers Retirement System (CalSTRS), one of the nation's largest pension funds, to pressure the company. CalSTRS owns about 8mn ExxonMobil shares.

An infusion of talent

Engine No 1 thinks ExxonMobil could very well be right about companies not investing enough to meet long term global energy demand. The problem is not necessarily amount but where ExxonMobil is spending it.

For example, ExxonMobil consistently says that it cannot justify spending lots of money on renewable energy projects because they do not offer attractive returns. But what is really lacking, Engine No 1 says, is leaders with the necessary expertise to help the company make those kind of decisions and the willingness to take such risks.

To that end, Engine No 1 said it will nominate four candidates with clean energy experience to ExxonMobil's board.

Alexander Karsner, a senior strategist at X, the innovation arm of Google, is especially noteworthy because his career spans the traditional oil and gas industry, clean energy, and Silicon Valley. Karsner was an investor in energy infrastructure firms like Enercorp and Tondu Energy Systems and served as US Assistant Secretary of Energy under the George W Bush administration, overseeing $2bn worth of federal R&D programs.

He was also a venture capitalist and advised Nest (which Google later acquired) and Tesla. ExxonMobil's board needs an infusion of such technology focused innovation talent, Engine No 1 believes.

Susceptible to pressure

ExxonMobil has successfully fought off activist challenges before. But there are signs that the major might be more vulnerable this time around.

Through the first nine months of this year, ExxonMobil has lost $2.3bn compared to a profit of $8.65bn during the same period in 2019, and said last week it expects to report in the fourth quarter an $18bn-$20bn write down related to its US shale operations. The company has tacitly acknowledged that the pandemic and rising concerns over climate change has altered its calculus.

In November, the company said it will reduce capex spending from 2022-2025 to $20bn-$25bn from its original plan of $30bn-$35bn. ExxonMobil also plans to triple cuts in methane emissions and nearly double flaring reductions at its upstream operations over the next five years, building on earlier targets.

"ExxonMobil has supported the goals of the Paris Agreement since its inception and is working to reduce emissions from our operations, while meeting the world's demand for affordable energy," the company said in a statement. "We continue to invest in and research breakthrough technologies that will play a key role in addressing the important issues related to climate change."

But ExxonMobil's actions has not appeased its critics. DE Shaw, which held 2.43mn shares of the company as of 30 September, is pushing management to cut capital spending to $13bn from a planned $16bn-$19bn this year. ExxonMobil has already committed to slash costs by $10bn by year's end but the hedge fund wants the company to further reduce expenses up to another $5bn.

A spokesperson from DE Shaw declined to comment.

New York State comptroller Thomas DiNapoli, who oversees the state's $226bn pension fund, recently announced that the fund has begun to review its portfolio of fossil fuel companies, including ExxonMobil, to determine their progress in transitioning to clean energy. The plan is to divest from firms "that do not meet standards" by 2025. The pension fund has already sold off its stakes in 22 coal companies.

CalSTRS and the New York State pension funds hold a combined 14.4mn shares in ExxonMobil.

What will BlackRock do?

Despite the backing of CalSTRS, Engine No 1 has a long way to go convincing other investors to back its campaign. Only three investors own more than 5pc of ExxonMobil stock: Vanguard (356mn shares), State Street Global Advisors (218.6mn shares), and BlackRock (210mn shares). Together, the investment firms control 18.4pc of ExxonMobil.

So even if Vanguard, State Street and BlackRock back Engine No 1, the activist firm still needs the support of a vast array of both institutional and individual investors who control the remaining 82pc.

But one factor works in Engine No 1's favor: the clout of proxy advisory firms Institutional Shareholder Services (ISS) and Glass Lewis, who advise institutional investors on how to vote on board candidates and shareholder proposals. ISS and Glass Lewis have previously backed shareholder resolutions against ExxonMobil, such as separating the chairman's role from the chief executive, but to no avail. But this time, investors might be more willing to listen, Engine No 1 thinks.

For example, BlackRock, which owns nearly 5pc of ExxonMobil shares, has said it will start to take into account climate change when managing its portfolio. In a letter to clients last year, BlackRock said it will prioritize "climate change, not only in terms of the physical risk associated with rising global temperatures, but also transition risk — namely, how the global transition to a low-carbon economy could affect a company's long-term profitability."

"We are making sustainability integral to the way BlackRock manages risk, constructs portfolios, designs products, and engages with companies," the letter continued. "We believe that sustainability should be our new standard for investing."

Veteran energy analyst Philip Verleger thinks ExxonMobil and other majors will capitulate in some way to activist investors.

"My expectation is that ExxonMobil will cut its capital expenditures and take other steps to appease the (activist) investors," Verleger said. "The Visigoths are attacking."


Related news posts

Argus illuminates the markets by putting a lens on the areas that matter most to you. The market news and commentary we publish reveals vital insights that enable you to make stronger, well-informed decisions. Explore a selection of news stories related to this one.

26/04/24

Lyondell Houston refinery to run at 95pc in 2Q

Lyondell Houston refinery to run at 95pc in 2Q

Houston, 26 April (Argus) — LyondellBasell plans to run its 264,000 b/d Houston, Texas, refinery at average utilization rates of 95pc in the second quarter and may convert its hydrotreaters to petrochemical production when the plant shuts down in early 2025. The company's sole crude refinery ran at an average 79pc utilization rate in the first quarter due to planned maintenance on a coking unit , the company said in earnings released today . "We are evaluating options for the potential reuse of the hydrotreaters at our Houston refinery to purify recycled and renewable cracker feedstocks," chief executive Peter Vanacker said on a conference call today discussing earnings. Lyondell said last year a conversion would feed the company's two 930,000 metric tonnes (t)/yr steam crackers at its Channelview petrochemicals complex. The company today said it plans to make a final investment decision on the conversion in 2025. Hydrotreater conversions — such as one Chevron completed last year at its 269,000 b/d El Segundo, California, refinery — allow the unit to produce renewable diesel, which creates renewable naphtha as a byproduct. Renewable naphtha can be used as a gasoline blending component, steam cracker feed or feed for hydrogen producing units, according to engineering firm Topsoe. Lyondell last year said the Houston refinery will continue to run until early 2025, delaying a previously announced plan to stop crude processing by the end of 2023. By Nathan Risser Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Azerbaijan wants certainty from EU on gas needs


26/04/24
26/04/24

Azerbaijan wants certainty from EU on gas needs

London, 26 April (Argus) — Azerbaijan needs long-term guarantees and available financial instruments to invest in gas production growth, its president Ilham Aliyev said earlier this week. Azerbaijan and the EU signed a strategic partnership agreement in 2022, in which Azerbaijan committed to increasing its supply to the EU to 20bn m³/yr by 2027 from 8bn m³ in 2021. This is a "target that we are moving towards" and exports to Europe will be around 12bn m³ this year, Aliyev said on 23 April at the Cop 29 and Green Vision for Azerbaijan forum ( see Azeri gas production graph ). But Azerbaijan needs investments to reach this export target, and restrictions from financing institutions on fossil fuel projects make them harder to realise, Alyiev said. The European Investment Bank has removed fossil fuel projects from its portfolio and the European Bank for Reconstruction and Development has only a small share of such projects, Aliyev said. Corporations tend to finance 30pc of gas production or infrastructure projects on their own and the remainder through loans, he said. The other issue is a need to receive long-term guarantees for Azeri gas supply, as "Azerbaijan cannot invest billions only for 5-10 years and not be able to recover the costs", Aliyev said. Azerbaijan is still paying back loans for the Southern Gas Corridor and Shah Deniz Stage 2 projects, he said. A long-proposed Ionian-Adriatic pipeline that could provide the Balkan region with Azeri gas is yet to materialise because it lacks EU funding support and gas consumption in the countries involved is low, particularly considering the challenges involved with building a pipeline in a mountainous region, Aliyev said. But Azeri gas can already reach Croatia, Bosnia Herzegovina and Montenegro through Hungary, while it can flow to Serbia through Bulgaria, he said. Aliyev said he believes that the Croatian and Azeri governments are already in consultation about this. Referring to a long-mooted project to build a pipeline across the Caspian Sea to deliver Turkmen gas to Europe, Aliyev said that Azerbaijan has "received no messages from Turkmenistan". Azerbaijan as a transit country cannot become the initiator or co-ordinator of a trans-Caspian pipeline project, Aliyev said. The Southern Gas Corridor is fully booked, meaning that infrastructure developments are needed to transport more gas to Europe, which is "under discussion", Aliyev said. Azerbaijan plans renewables build-out Azerbaijan is targeting 5GW of additional renewable generation capacity, which it aims to substitute for gas, releasing this supply for export to Europe, Aliyev said. Azerbaijan's first 240MW solar plant was inaugurated in 2023. It plans to add four new 1.3GW solar and wind projects this year and is considering some offshore and onshore wind projects as well as solar and hydropower plants. Azeri gas consumption for power generation and heating needs increased to 6.6bn m³ in 2022 from 6.1bn m³ in 2020, and made up almost half of domestic consumption in 2022 ( see data and download ). Azerbaijan is in the last phase of a feasibility study for a green energy cable from the Caspian Sea to the Black Sea and then further down to Europe. The project aims to initially connect the Georgian Black Sea to the Romanian coast, and plans to expand it further down to the eastern Caspian and Kazakhstan, according to Aliyev. The state plans to keep investing to strengthen the energy grid to allow it to cope with the renewables build-out. Foreign investors are mainly involved with renewables projects. Oil and gas makes up less than half of Azerbaijan's GDP today, but 95pc of its exports, Aliyev said. By Victoria Dovgal Azeri gas production bn m³ Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

US M&A deals dip after record 1Q: Enverus


26/04/24
26/04/24

US M&A deals dip after record 1Q: Enverus

New York, 26 April (Argus) — US oil and gas sector mergers and acquisitions (M&A) are likely to slow for the rest of the year following a record $51bn in deals in the first quarter, consultancy Enverus says. Following an unprecedented $192bn of upstream deals last year, the Permian shale basin continued to dominate first-quarter M&A as firms competed for the remaining high-quality inventory on offer. Acquisitions were led by Diamondback Energy's $26bn takeover of Endeavor Energy Resources. Other private operators, such as Mewbourne Oil and Fasken Oil & Ranch, would be highly sought after if they decided to put themselves up for sale, Enverus says. Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Start-ups to help Total keep output stable in 2Q


26/04/24
26/04/24

Start-ups to help Total keep output stable in 2Q

London, 26 April (Argus) — TotalEnergies said it expects its oil and gas production to hold broadly steady in the second quarter as planned maintenance is partially offset by rising output from new projects in Brazil and Denmark. The company expects to average 2.4mn-2.45mn b/d of oil equivalent (boe/d) in April-June, compared with 2.46mn boe/d in the previous three months and 2.47mn boe/d in the second quarter of 2023. Production is being supported by the restart of gas output from the redeveloped Tyra hub in Denmark late last month and the start of the 180,000 b/d second development phase of the Mero oil field on the Libra block in Brazil's Santos Basin at the beginning of the year. TotalEnergies first-quarter output was flat compared with the previous three months but 2pc lower than a year earlier as a result of Canadian oil sands divestments. The company reported a robust set of first-quarter results today, broadly in line with analysts' expectations. Profit for the first three months of 2024 was $5.7bn, compared to $5.6bn in the same period last year. Adjusted profit — which takes into account inventory valuation effects and special items — came in at $5.1bn, down by 22pc on the year but slightly ahead of the consensus of analysts' estimates of $5bn. Adjusted operating profit from the firm's Exploration & Production business was down by 4pc year-on-year at $2.55bn, driven in part by lower natural gas prices. The Canadian oil sands asset sales weighed on the segment's production but this was partly compensated by start-ups. As well as Mero 2, the Akpo West oil project in Nigeria started production during the first quarter. TotalEnergies' Integrated LNG segment saw a 41pc year-on-year decline in its adjusted operating profit to $1.22bn in January-March. The company said this reflects lower LNG prices and sales. But while its LNG sales for the quarter fell by 3pc in year-on-year terms, its LNG production was greater by 6pc. TotalEnergies achieved an average $78.9/bl for its liquids sales in the first quarter, an improvement on $73.4/bl a year earlier. But the average price achieved for its gas sales was 43pc lower on the year at $5.11/mn Btu. In the downstream, the company's Refining & Chemicals segment's first-quarter adjusted operating profit was $962mn in January-March, down by 41pc on the year but 52pc higher than the preceding quarter. TotalEnergies attributes the quarter-on-quarter rise to higher refining margins and a rise in refinery throughput . For the second quarter, it expects refinery utilisation rates to be above 85pc, compared with 79pc in the first quarter, boosted by the restart of 219,000 b/d Donges refinery in France. Total's Integrated Power segment continued to improve, registering a quarter-on-quarter and year-on-year increased of 16pc and 65pc respectively in its adjusted operating profit to €611mn. Net power production increased 14pc year-on-year to 9.6 TWh, while the company's portfolio of installed power generation capacity grew 54pc to 19.5GW. Total's cash flow from operations, excluding working capital, was down by 15pc on a year earlier at $8.2bn in the first quarter. The company has decided to raise its dividend for 2024 by 7pc to €0.79/share and plans a $2bn programme of share buybacks for the second quarter. By Jon Mainwaring Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

India's crude output steady, throughput rises in March


26/04/24
26/04/24

India's crude output steady, throughput rises in March

Mumbai, 26 April (Argus) — India's March crude production was steady on the year and up by 2pc on the month at 543,000 b/d. Output fell by 2pc to 546,000 b/d during the April 2023-March 2024 fiscal year. Total crude and condensate production was 590,000 b/d in March, up from 580,000 b/d in February and steady from March 2023, data from the oil ministry show. Crude output from state-controlled upstream firm ONGC was 354,000 b/d in March, up by 0.2pc on the month and down by 6pc on the year. This was likely because of a shutdown at the Panna-Mukta offshore platforms to commission a new crude pipeline and to modernise its evacuation facilities. The windfall tax for domestic crude production was raised to 4,600 rupees/t ($7.58/bl) during 1-15 March and then to Rs4,900/t during 16 March-3 April. The rate is reviewed every two weeks. The Indian government first imposed the windfall tax in July 2022 as a sharp increase in crude prices then resulted in domestic crude producers making windfall gains. Indian crude producers sell crude to domestic refineries at international parity prices. ONGC and fellow state-controlled upstream firm Oil India continued to produce the most of India's crude in March at 425,000 b/d, making up 78pc of the total production. Private-sector producers and joint ventures made up the remainder. India's dependence on crude imports declined to 88pc in March from 89pc in February and March 2023. Its dependence on crude imports rose to around 88pc in April 2023-March 2024 from 87pc in the previous year. India has steadily been trying to reduce its dependence on imports. It extended the deadline to 15 May for submitting bids for 28 upstream oil and gas blocks in the ninth Open Acreage Licensing Program bidding round. India's oil product exports fell to 5.3mn t in March from 6mn t in March 2023, but rose from 4.1mn t in February. Higher throughput Indian refiners processed 5.53mn b/d in March, higher from 5.28mn b/d in February and 5.44mn b/d in March 2023. Processing rose to 5.24mn b/d in April 2023-March 2024, up from 5.11mn b/d the previous year. Processing likely picked up as product demand increased in March. India's product demand — including diesel, gasoline, jet fuel, LPG, bitumen, naphtha and petroleum coke — increased by nearly 7pc from the previous month and was steady on the year to 21mn t in March. Crude throughput at state-controlled IOC's nine refineries was 1.6mn b/d, up by 8pc from a year earlier and by 10pc against the previous month. State-controlled BPCL processed 874,000 b/d at its refineries in March, up by 3pc from a year earlier and by 8pc from February. State-controlled HPCL's throughput rose by 3pc from the previous year and was steady from a month earlier at 709,000 b/d. ONGC's refineries processed 354,000 b/d in March, 6pc lower on the month and steady against a year earlier. India imported 4.7mn b/d of crude in March, 4pc lower from the previous year and up by 4pc from a month earlier, according to oil ministry data. By Roshni Devi Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Business intelligence reports

Get concise, trustworthy and unbiased analysis of the latest trends and developments in oil and energy markets. These reports are specially created for decision makers who don’t have time to track markets day-by-day, minute-by-minute.

Learn more