Big Oil gets its place at the climate table

  • Market: Crude oil, Emissions, Natural gas
  • 21/08/23

Two years after objecting to being frozen out of the Cop 26 UN climate conference in Glasgow, the oil and gas industry is expecting a very different reception at this year's meeting, with host country the UAE stressing the importance of fossil fuel producers having a seat at the table. But with that seat will come increased scrutiny on the industry and how it uses the platform to stake its claim to become part of the solution in the fight against climate change.

Much has been made of the decision to select the UAE as host of Cop 28. The country is already a major oil and gas producer and is several years into a programme to expand its production. Non-governmental organisations initially warned that giving the top Cop 28 job to Sultan al-Jaber, the long-time chief executive of Abu Dhabi's state oil company Adnoc, would "hurt the UAE's credibility in the role" and "set a dangerous precedent".

The backlash was hardly unexpected. Oil and gas operations account for nearly 15pc of energy-related greenhouse gas emissions, the IEA says, while consumption of oil and gas accounts for another 40pc. Conventional wisdom says oil and gas have long been part of the problem and need to be phased out, not encouraged. It was that sentiment that informed the decision to exclude some of the industry's biggest names from taking an active role in the Glasgow Cop. Many oil companies did not attend, and those that went tried to keep a low profile.

The snub did not sit well with the industry. Opec's then secretary-general, the late Mohammed Barkindo, lamented that the sector was "ostracised" from the summit. Oil and gas producers need to be included in planning for the transition to cleaner forms of energy, Barkindo said.

Doing things differently

At last year's Cop conference, hosted by Egypt, the industry was more visible. Saudi Arabia hosted its Middle East Green Initiative (MGI) summit in Sharm el-Sheikh, just outside the UN zone, featuring TotalEnergies chief executive Patrick Pouyanne and Saudi state-controlled Aramco chief executive Amin Nasser.

But this year in Dubai, al-Jaber, who is also the chairman of the country's state-owned renewables firm Masdar, wants the oil and gas industry to have a presence in order to leverage its expertise. Cop 28 chief executive Adnan Amin says they want to bring the oil and gas sector "to the table and bring them to the framework of accountability in front of the international community", adding that he understands the "legitimate concerns" this might bring.

"We need to be at that table," one senior executive from a Mideast Gulf hydrocarbons producer says. "Oil and gas make up close to 55pc of our primary energy mix today. How can you ignore that? We can do a lot, we just need to be part of the discussion." What the industry hopes to see at Cop 28 is a shift in the general narrative around the energy transition and the actions that need to be taken, but also in the sentiment towards the industry and the role it can and should be playing in the transition towards cleaner energy. "We owe it to ourselves and our industry to show up," BP chief executive Bernard Looney says.

But what a more formal participation of the oil and gas sector will look like at Cop 28 remains unclear. The UNFCCC — the UN's climate arm — is a party-driven process, civil society organisation Oil Change International campaign manager David Tong says. "The presidency has formal and informal ways in shaping discussions, but there is no framework for a direct dialogue in formal sessions between one industry and governments," Tong says.

Oil and gas companies and organisations have so far not rushed to confirm their participation. Shell talks about having a low-key presence, to "listen to discussions and engage with key stakeholders", but others have declined to comment on the record.

"Mideast Gulf producers like the UAE, like Saudi Arabia… they want co-operation on these climate issues, not to be painted as the enemy by environmentalists," consultancy Energy Outlook Advisors managing partner Anas Alhajji says. "They accept that energy consumption is growing and that we need renewables like solar or wind… But what they say is to use those energies for the right applications, where it makes sense, alongside traditional oil and gas."

The opportunity for the industry to work in concert with governments on these issues will open more avenues to share expertise and technologies that few outside the hydrocarbons sector may be familiar with. This could include, for example, ways of integrating the use of renewables into the hydrocarbon framework. "Using wind or solar to power operations at remote oil and gas fields would work, instead of having to ship diesel long distances," Alhajji says. "Sharing information like this becomes extremely important."

The climate debate has become "too ideological", industry executives say, which has complicated their efforts to engage in a meaningful way. They hope this summit can begin to change that. A big part of this will rest with them and what they bring to the table. But for many observers, it is unlikely to be enough.

The industry's biggest players have long acknowledged that more needs to be done to deliver what the UN Intergovernmental Panel on Climate Change (IPCC) says is needed to limit global temperature rises to no more than 1.5°C compared with pre-industrial averages by the end of the century. Projected CO2 emissions from "existing fossil fuel infrastructure without additional abatement would exceed the remaining carbon budget for 1.5°C", the IPCC says. Many in the industry say they are open to doing more to curb their emissions, but want clear and long-term policy guidance from governments, with a "clear roadmap for investment".

Scope 3 elephant

Al-Jaber urges the entire industry to achieve net zero by or before 2050. Cop 28's Amin previously said they are also working on a 2030 target — although this could prove more difficult — and towards net zero methane emissions by 2030. This could translate into a pledge made on the sidelines of Cop 28, or even before the summit. TotalEnergies' Pouyanne said at the Opec Seminar in Vienna last month that international and national oil companies should commit to signing up to 2030 reduction targets for Scope 1 and Scope 2 emissions — those from the production, transport and processing of oil and gas.

Adnoc last month announced that it had brought forward its target to reach net zero emissions from its operations by five years to 2045. This has put "an expectation on other oil producers to follow suit", Alhajji says, to demonstrate the industry's commitment and seriousness.

But one topic notable by its absence from the industry's discussions ahead of Cop 28 is what to do about Scope 3 emissions — those from the use of oil and gas. The issue comes back to the question of who has responsibility for the emissions — the producer or the consumer? And while some companies are taking steps to counter a portion of their Scope 3 emissions, others continue to argue that customers have their part to play. Al-Jaber's ambition for industry-wide net zero by 2050 appears to only cover Scope 1 and 2 emissions.

A deal that excludes the industry's Scope 3 emissions would "lack credibility", Tong says. If Adnoc can step up and bring to the table other national oil companies, and they can show that they are starting to grapple with the need to transition from oil and gas, this could be "powerful" — but this is unlikely, according to Tong.

Majors' stated emissions goals
CompanyScope 1 and 2Scope 3Net zero by 2050?
BP*20% reduction by 2025, 50% by 203010-15% reduction by 2025, 20-30% by 2030Y
Chevron†5% reduction by 2028, net zero by 2050 5% reduction by 2028N
ExxonMobil‡30% reduction within upstream operation by 2030, 20% across entire company by 2030, net zero by 2050-N
Shell‡50% reduction by 20309-13% reduction by 2025Y
TotalEnergies#40% reduction by 203030% reduction by 2025, 40% by 2030Y
*2019 baseline. Scope 3 targets lowered in early 2023 from 20% by 2025 and 35-40pc by 2030
†2016 baseline. Chevron uses a portfolio carbon intensity target that includes Scope 1, 2 and 3
‡2016 baseline
#2015 baseline

Oil companies' Scope 1 and 2 targets

Sharelinkedin-sharetwitter-sharefacebook-shareemail-share

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.

News
10/05/24

California refineries required to report turnarounds

California refineries required to report turnarounds

Houston, 10 May (Argus) — Refiners in California starting in June must file maintenance schedules with the state's energy commission at least 120 days in advance of planned work, and diagnostic reports within two days of unplanned shutdowns. The new reporting requirements, part of the SB X1-2 bill passed in March 2023, take effect following an 8 May meeting of the California Energy Commission (CEC) where the measures were finalized. The CEC will now be able to gather a broad range of data from refiners and set a maximum gross gasoline refining margin in an effort to avoid price spikes at the pump. If companies identify a need for maintenance less than 120 days before the planned work, a report to the CEC is required within two business days of the discovery, according to the reporting form posted in the SB X1-2 docket. The reporting form includes space for a description of the work, unit level details and information on the expected effect of a turnaround on transportation fuel inventories at the refinery. The same information will be required for unplanned maintenance, with a report to be sent to the CEC within two business days of the initial outage or lowered rates, and within two business days of the completion of work or return to normal throughputs. The additional information will aide the CEC in analyzing refiner margins and determine whether a margin cap and subsequent penalties are warranted, according to the commission. Industry groups think many of the reporting requirements are burdensome and politically motivated , often requesting information unnecessary to determine margins. Marine import reporting on horizon At the same 8 May business meeting, the CEC moved closer to finalizing a requirement for importers of foreign and domestic refined products and renewable fuels to report shipments at least four days before delivery. The reporting form includes information on vessel routes, costs and products shipped. The CEC approved for the marine reporting requirements to be submitted to the state's Office of Administrative Law for a 10-day review before a targeted 20 May start date. By tracking import data, the CEC aims to build a more accurate picture of what drives retail fuel prices and refiner margins in the state. "In many cases these forms request information that has questionable or no relevance at all to the CEC's efforts to minimize or prevent price spikes," said Sophie Ellinghouse, general counsel for trade group the Western States Petroleum Association, during public comments on the marine reporting requirements at the 8 May meeting. By Nathan Risser Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Find out more
News

Mexican power outages enter fourth day


10/05/24
News
10/05/24

Mexican power outages enter fourth day

Mexico City, 10 May (Argus) — Mexican power grid operator Cenace issued its fourth consecutive day of operating alerts amid the heatwave gripping the country. Net electricity demand reached 47,321MW early today, with deployed electricity capacity slightly below at 47,233 MW, according to Cenace. Since 7 May, Cenace has declared emergency operating alerts as demand exceeded generation capacity during peak evening hours, prompting the grid operator to preemptively cut electricity supply across different states to maintain grid integrity. Power outages have lasted up to several hours in Mexico City and in major industrial states as power demand has outstripped supply by up to 1,000MW. Peak demand this week hit 49,000MW, just below last year's historic peak of 53,000MW during atypical temperatures in June. "We are very concerned about the unprecedented outages detected across 21 states, a situation that affects the normal functioning of Mexican companies," national business chamber Coparmex said. Peak electricity demand typically rises in June-July but temperatures this week have risen as high as 48°C (118° F) across some states. Mexico City reported a record high of 34.3°C on 9 May and high temperatures are forecast to continue into next week, Mexico's national weather service said. The inability of Mexico's grid to respond to increased demand is because of insufficient power generation capacity, non-profit think-tank the Mexican institute for competitiveness (Imco) said this week. "Despite the energy ministry's forecast that 22,000MW of new power capacity would enter service by 2026, only 1,483MW had entered service as of 2022" since late 2018, Imco said. President Andres Manuel Lopez Obrador's administration pledged to build new generation capacity, including five gas-fired, combined-cycle plants, but recognized this week that delays had contributed to the power outages. "We have an electricity generation deficit because some of the combined-cycle plants were delayed, but we are working on it and it will soon be resolved," Lopez Obrador said on 9 May. Lopez Obrador's government has also curtailed private sector power development during his administration. Mexico needs to upgrade and expand its transmission network, industry associations say. "In order to resolve this problem, we believe that a reopening of the electricity market to the private sector is imperative," Mexico's wind energy association, Amdee, said. Mexico has 87,130MW of installed capacity, with 39.5pc from combined-cycle gas-fired power plants and 31pc in renewable power, including wind, solar, hydroelectric, geothermal and biomass, according to the latest statistics from the energy ministry. By Rebecca Conan Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

News

Petrobras to expand free gas market footprint


10/05/24
News
10/05/24

Petrobras to expand free gas market footprint

Rio de Janeiro, 10 May (Argus) — Petrobras said today it will offer new types of natural gas contracts in Brazil's open market with more flexibile and competitive terms, but provided no details on the planned offers. The company also announced new commercial contract models for gas sales to state distributors, offering price reductions for current contracts of up to 10pc. The reduction will be connected to the distributors performance, Petrobras said, without providing more detail. The move by the state-controlled giant is significant given the 2021 gas market liberalization as aimed at increasing competition at every step of the value chain beyond just Petrobras. But progress has been slow in cutting Petrobras' market share, lowering prices, and increasing market transparency. The 2021 gas law covers the full lifecycle of natural gas, from production to transportation, processing to storage, and sales. A key provision aimed at promoting competition in the upstream, midstream, and downstream sectors, particularly transportation and distribution. Yet, three years later, there is little sign of downstream customers migrating to the free market, despite some moves such as those from Delta Geração, Acelen, Gerdau, Tradener, and others. The number of free market commercial contracts does not exceed ten, according to a lawyer specialized in the energy market. By Betina Moura Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

News

Russia leads Opec+ output fall


10/05/24
News
10/05/24

Russia leads Opec+ output fall

London, 10 May (Argus) — Opec+ crude output by members subject to cuts fell by 440,000 b/d in April as Russia began implementing a fresh cut and Iraq and Kazakhstan curbed some of their overproduction. This saw the group's production fall to 34.11mn b/d, which was 140,000 b/d above quota, Argus estimates. Still, this was a marked improvement on the 230,000 b/d overproduction that it recorded in March. The lower production has not provided much support to oil prices, which have shed $5-8/bl in the past month. Several members of the alliance are implementing a new set of "voluntary" cuts that came into effect in January and, for now, run to the end of June. What Opec+ decides to do beyond this will probably be decided at a ministerial meeting in Vienna on 1 June, although the likelihood of a rollover has grown as oil prices have fallen. The big mover last month was Russia, whose output fell by 210,000 b/d to 9.29mn b/d. The drop is related to Russia's pledge to start phasing out an existing 500,000 b/d export cut commitment from April and replace it with a 471,000 b/d production cut by June. But the country remained 190,000 b/d above its new 9.1mn b/d target for April. And while the output fall shows Russia has made headway with its pledge to reduce production, sanctions on the country's oil industry and Ukrainian attacks on its refineries could affect its crude output in the months ahead. Iraq and Kazakhstan also reduced their output last month, while remaining well above target. Iraqi output fell by 40,000 b/d to 4.14mn b/d, mostly owing to lower crude use by the power sector. But this was still around 140,000 b/d above its target of 4mn b/d. Kazakhstan's output fell by 40,000 b/d to 1.54mn b/d — the second month in a row that its output has fallen. But it was also still around 70,000 b/d above its target of 1.47mn b/d. Compensation plans Iraq and Kazakhstan have each submitted plans to the Opec+ Joint Ministerial Monitoring Committee detailing how they intend to compensate for producing above target in the first four months of the year. As things stand, Iraq says it will produce 50,000 b/d below quota in May-September, 100,000 b/d below quota in October-November and 152,000 b/d below quota in December. Kazakhstan's compensation plan starts in May with an initial cut of 18,000 b/d below target. It would then stick to its target in June and July before implementing a cut of 131,000 b/d in August, no cut in September, 299,000 b/d in October, 40,000 b/d in November and no cut again in December. The two countries' plans are dependent on a final production figure for April from secondary sources — including Argus — and could be adjusted after it becomes available. Nigerian production recorded a large fall in April, dropping by 100,000 b/d to 1.4mn b/d, the lowest since 1.28mn b/d in August 2023. This left the country 100,000 b/d below its target of 1.5mn b/d. Production was relatively uneventful in the Mideast Gulf Opec+ contingent. Saudi Arabia's output fell by 30,000 b/d to 8.97mn b/d, the UAE's fell by 20,000 b/d to 2.93mn b/d, Kuwait's dropped by 20,000 b/d, while Bahrain's production increased by 30,000 b/d to 190,000 b/d. All four members were more or less within their targets. Iran, which like Libya and Venezuela is not bound by production targets, boosted its output by another 20,000 b/d to 3.3mn b/d — the highest since October 2018. The gains have come despite US sanctions and Washington's attempts to crack down on the country's oil trade. Opec+ crude production mn b/d Apr Mar* Apr target† ± target Opec 9 21.32 21.54 21.22 0.10 Non-Opec 9 12.79 13.01 12.75 0.04 Total Opec 18 34.11 34.55 33.97 0.14 *revised †includes additional cuts where applicable Opec wellhead production mn b/d Apr Mar* Apr target† ± target Saudi Arabia 8.97 9.00 8.98 -0.01 Iraq 4.14 4.18 4.00 0.14 Kuwait 2.41 2.43 2.41 -0.00 UAE 2.93 2.95 2.91 0.02 Algeria 0.91 0.92 0.91 0.00 Nigeria 1.40 1.50 1.50 -0.10 Congo (Brazzaville) 0.28 0.25 0.28 0.00 Gabon 0.23 0.25 0.17 0.06 Equatorial Guinea 0.05 0.06 0.07 -0.02 Opec 9 21.32 21.54 21.22 0.10 Iran 3.30 3.28 na na Libya 1.22 1.18 na na Venezuela 0.82 0.85 na na Total Opec 12‡ 26.66 26.85 na na *revised †includes additional cuts where applicable ‡Iran, Libya and Venezuela are exempt from production targets Non-Opec crude production mn b/d Apr Mar* Apr target† ± target Russia 9.29 9.50 9.10 0.19 Oman 0.76 0.76 0.76 0.00 Azerbaijan 0.48 0.48 0.55 -0.07 Kazakhstan 1.54 1.58 1.47 0.07 Malaysia 0.35 0.35 0.40 -0.05 Bahrain 0.19 0.16 0.20 -0.01 Brunei 0.08 0.08 0.08 -0.00 Sudan 0.02 0.02 0.06 -0.04 South Sudan 0.08 0.08 0.12 -0.04 Total non-Opec† 12.79 13.01 12.75 0.04 *revised †includes additional cuts where applicable Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

News

California fuel retailers fear regulatory scrutiny


10/05/24
News
10/05/24

California fuel retailers fear regulatory scrutiny

Houston, 10 May (Argus) — US fuel retailers like neither the regulatory precedent being set in California nor how the transition to renewable fuels is being managed, but companies sticking it out in the Golden State may reap rewards. California governor Gavin Newsom (D) in March last year signed SB X1-2 into law, allowing the California Energy Commission (CEC) to gather a broad range of profit data from refiners and set a maximum gross gasoline refining margin in an effort to avoid price spikes at the pump. "Unfortunately in California there is no shortage of bad policies that are being proposed," California Fuels and Convenience Alliance director Alessandra Magnasco said this week in a legislative affairs meeting at fuel retailer trade association SIGMA's conference in Austin, Texas. She worries that if the CEC fails to make progress in capping margins at the refiner level, they will look further downstream and regulate retailers. The alliance is opposed to what it sees as burdensome reporting requirements mandated by SBX 1-2 that were rushed through the legislature. "They are doing it in a way to leave out industry," Magnasco said. The CEC this week approved further reporting requirements for refiners in the state, mandating they file maintenance schedules with the commission at least 120 days in advance of planned work and within two business days after the start of unplanned shutdowns. "Every bad idea we face has generally been socialized in California first," David Fialkov, vice president of government affairs for US fuel retailer trade association NATSO, said during the SIGMA session. The increased adoption of renewable diesel in California is also causing headaches for fuel supply managers. "I can't even tell my customers which specific terminal might have traditional diesel versus renewable or if they're going to have both," said Deborah Neal, director of price risk management for fuel supplier World Kinect during another SIGMA panel discussion. The introduction of renewable diesel to the California market was done without a specific time line or transition plan, Neal said. "It's messy to say the least." The regulatory environment in California has also dampened appetite for mergers and acquisition activity in the eyes of bankers doing the deals. Gas station buyers who are looking to consolidate smaller assets are not looking at California if they are not already invested there, Matrix Capital Markets' co-head of downstream energy investment banking Cedric Fortemps said at SIGMA. "The operating and legal dynamics are completely different than other parts of the country," Fortemps said. But for companies already operating in California, there is limited out-of-state competition and high barriers to entry. Those companies are keen to grow their existing operations, Fortemps said. By Nathan Risser 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