Cop 26 profile: Europe sets climate bar high

  • : Crude oil, Emissions, Natural gas, Oil products
  • 21/10/22

The bloc hopes the summit will see other major emitters deliver concrete plans for net zero, writes Dafydd ab Iago

The EU has dominated global climate talks since the first UN Conference of the Parties (Cop) summit in Berlin, in addition to holding the UN Framework Convention on Climate Change secretariat in the former German capital Bonn. On top of hosting more than half of the Cops since 1995, Europe has become the first major economic region to lay out in detail a policy path towards net zero carbon emissions in 2050.

"Europe needs to lead, so the rest of the world understands where we need to go," EU climate action commissioner Frans Timmermans told EU environment ministers signing off this month on the bloc's negotiating mandate for Cop 26. That self-image of a bloc leading with ambitious headline targets, and detailed EU and national legislation, is key to the EU's negotiating position in Glasgow.

Having surpassed its previous 20pc reduction target set for 2020, the EU submitted confirmation, this May, to the UN of EU-level emission cuts of 3.8pc in 2019 compared with 2018. That is a full 24pc lower than 1990 levels, even before Covid-19 restrictions cut greenhouse gas (GHG) emissions last year. The bloc also updated its nationally determined contribution (NDC) and legally bound itself to carbon neutrality by 2050 and cutting GHG emissions in 2030 by at least 55pc compared with 1990, up from a previous 40pc target (see table).

For Brussels then, Glasgow must force other major emitters, such as China and the US, to deliver with concrete plans rather than vague commitments towards net zero. European Commission president Ursula von der Leyen only sees China's announcement at the UN that it will stop building coal-fired generation abroad or US president Joe Biden's promise to double US international climate finance as "steps in the right direction". While repeating a promise to commit an additional €4bn ($4.7bn) in climate finance in 2021-27, von der Leyen wants "concrete" plans from international partners. The EU brings to Glasgow the highest level of ambition. "We do it for our planet. And we do it for Europe," she told the European Parliament this month.

If altruism does not push other Cop parties into action, the EU is fine-tuning a carbon border mechanism to protect its carbon-intensive industries. The mechanism starts in 2026 with a duty on cement, iron and steel, aluminium, fertiliser and electricity imported to the EU from countries not subject to carbon pricing.

Concrete carbon phase-outs

Polishing the money aspects of the bloc's negotiating position for Glasgow, finance ministers from the EU's 27 member states stress that the "ambitious" updated NDC is being implemented by a package of legislative proposals adopted by the commission in July. And Timmermans warned environment ministers this month against using the energy price shocks that EU members are facing as an excuse to back down on proposals that are effectively phase-out schedules for CO2-intensive sectors. Timmermans said that if Europe leaves the climate crisis untackled, the resulting social unrest will be far worse than France's 2018 gilets jaunes protests over fuel and climate taxes.

More climate sceptical — and coal dependent — Poland is, for the moment, relatively isolated in arguing for postponing or lowering various climate and energy goals because of the energy price spikes. The majority of EU politicians seem to accept calls by Timmermans and von der Leyen to double down on decarbonisation policies such as an increased GHG cut — of 61pc, rather than 43pc, by 2030, compared with 2005 levels — for industries under the bloc's emissions trading system (ETS). Distributors of road and heating fuels will have to purchase allowances, from 2026, to cover their emissions under a separate ETS with a carbon price that may well float above €100/t. In aviation, allowances for intra-European flights will be slowly reduced, with operators losing free allowances from 2026.

The EU's commitment to delivery is evidenced by over 3,000 pages of dense legal proposals and explanatory texts that aim to set GHG fuel intensity cuts for maritime fuels, oblige flight operators to take up 5pc sustainable aviation fuels by 2030, rising to 20pc by 2035 and 63pc by 2050, and for renewables to reach 40pc, rather than 32pc previously, of EU gross final consumption of energy by 2030.

Tougher CO2 emissions standards for new passenger cars and vans require average emissions to come down by 55pc from 2030 and by 100pc from 2035, compared with a 2020-21 target of 95g CO2/km​. That effectively sets a 2035 phase-out date for sales of unabated internal combustion engines. There is also a 13pc GHG intensity reduction target for transport fuels by 2030, effectively doubling to 28pc the share of renewable fuels in road transport.

Ships calling at EU ports will have to reduce the average GHG intensity of their fuels by 6pc by 2030, 13pc by 2035 and 75pc by 2050, all from 2020 levels. And the commission wants member states to push zero-emission car sales by equipping major highways with electric charging every 60km and hydrogen refuelling every 150km.

Article 6 integrity

Signing off on a negotiating mandate for Timmermans and the commission in Glasgow, EU environment ministers have called for article 6 of the Paris climate agreement to set rules for international carbon trading that are "consistent with the necessary increased global ambition and the achievement of climate neutrality, and that avoid double counting and lock in to high-emissions pathways". Ministers specifically want article 6 provisions that promote sustainable development, ensure environmental integrity and ambition, and address risks such as "non-permanence" of carbon cuts or sequestration and "leakage" from projects.

Off the record, EU officials involved in the nitty-gritty of climate negotiations are openly sceptical about international carbon trading, flagging an increasing number of complaints about the credibility of voluntary offsets with "different controversies in different countries". Officials fear double counting and the need for "corresponding" adjustments of their own emission figures when countries sell reductions to others. "Fostering global ambition, ensuring environmental integrity and avoiding double accounting are at the core of the Paris agreement and of the EU position on market mechanisms," European environment commissioner Virginijus Sinkevicius says.

The EU's non-governmental organisations have called the bloc's negotiating position "good enough", especially as EU ministers now back a five-year timeframe for countries' NDCs to the Paris agreement to be implemented from 2031. But campaigners say the EU27 have intentionally left their negotiators room to manoeuvre, including on how the EU and member states will help reach the €100bn goal for international climate finance for developing countries. And non-governmental organisation Carbon Market Watch wants the EU to do more to ensure international carbon market negotiations move beyond just compensating emissions and zero-sum offsetting to deliver real GHG reductions. It calls for tough offsetting and carbon trading rules at Cop 26, and will this month present critical analysis of claims by companies including Shell, Total, BP, Russian state-controlled Gazprom and Chinese state-controlled PetroChina of carbon-neutral natural gas and crude shipments.

EU GHG reduction targets
NDC target % Baseline yearTarget year
2016 — 40pc19902030
2020 — 55pc 19902030
2016 — 80-95pc19902050
2020 — 100pc19902050

EU GHG emissions by source

Net EU electricity generation, 2019

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24/05/08

Baltic April gas consumption rises on year

Baltic April gas consumption rises on year

London, 8 May (Argus) — Gas demand in the three Baltic states and Finland was up by 26pc on the year in April, although there were diverging trends in the different markets. Consumption in Finland, Estonia, Latvia and Lithuania totalled 3.56TWh, up from 2.82TWh a year earlier but down from 4.31TWh in March ( see data and download, graph ). That said, total demand was still well below the 2018-21 average for the month of 5.03TWh. Consumption was up on the year in all three Baltic countries, but Finnish demand edged down. This was the first month in which Finnish demand was lower on the year since April 2023. In contrast, Lithuanian consumption surged by nearly 50pc on the year, and was also higher than in February and March despite the end of the traditional heating season. Gas-fired power generation held broadly stable from a year earlier, totalling 305MW across the four countries compared with 301MW in April last year ( see gas-fired output table ). Output edged down in Estonia and Lithuania and dropped by 25MW in Finland, but this was offset by a 31MW increase on the year in Latvia. But, unlike in March, gas-fired output fell by 246MW, a large contributing factor to the lower gas demand on the month. Many combined heat and power plants will have switched off at around the end of March or mid-April as the traditional heating season came to a close, possibly driving the fall in gas-fired output. But renewables generation was also stronger in April than March, particularly in Finland, where wind output rose to 2.03GW from 1.63GW, while hydro also stepped up. In Lithuania, solar and waste-based production increased on the month. Demand was also stronger despite higher year-on-year minimum temperatures in all four capital cities, which may have curbed most residual heating demand after the end of the traditional heating season, although there was a brief cold snap towards the middle of the month that temporarily drove up demand ( see temperatures table ). With gas-fired power generation only marginally higher than a year earlier, and the warmer weather curbing residential demand, a possible uptick in industrial demand may have driven the aggregate rise in consumption. Average prices on the regional GET Baltic exchange were €33.30/MWh in April, up by 8pc on the month but 30pc lower than a year earlier, the exchange said. Prices increased in around the middle of April "due to the unexpectedly cold weather and the increased demand for gas in the market", but then fell again "as the weather warmed", GET Baltic chief executive Giedre Kurme said. There were a total of 2,400 transactions last month for a combined 642GWh of gas. Volumes sold on the Finnish market accounted for 42pc, the joint Latvian-Estonian market 33pc, and the remaining 25pc was sold in Lithuania. Klaipeda and Balticconnector to change flows The return of the Finnish-Estonian Balticconnector pipeline and the start of maintenance at the Klaipeda LNG terminal in Lithuania will drive changed flow patterns this month. The Balticconector resumed commercial operations on 22 April after being off line since 8 October following a rupture caused by a dragging ship anchor . The reconnection of Finland to its southern neighbours has allowed for strong southward flows since 22 April, at an average of 62 GWh/d on 22 April-7 May. Some of this gas is probably being injected into storage, with the region's only facility at Incukalns switching to net injections on 23 April from net withdrawals of 7 GWh/d earlier in the month. Net injections have since averaged 46 GWh/d on 23 April-6 May, the latest data from EU transparency body GIE show. Stocks at Incukalns ended the withdrawal season on 30 April at 11.29TWh, the highest since at least 2014 and well above the previous high from last year of 9.03TWh. Large volumes of gas that had been stored over the previous summer for export to Finland over the winter were left stranded in Incukalns after the Balticconnector went off line. And the Klaipeda LNG terminal began maintenance on 1 May, which will last until 15 June, as the terminal's Independence floating storage and regasification unit (FSRU) departed for dry-docking in Denmark. As a result, there were net exports from Poland to Lithuania for the first time since early November, at an average of 17 GWh/d on 1-7 May. Some of this gas could have been withdrawn from Ukrainian storage, with flows from Ukraine to Poland averaging 10 GWh/d over the same period. Lithuania's largest supplier Ignitis has said it stored some volumes in Ukraine. And flows at the Kiemenai border point with Latvia have also flipped towards Lithuania, averaging 11 GWh/d on 1-7 May, compared with net flows towards Latvia of 15 GWh/d in April. That said, there were no flows at the point on 6-26 April. By Brendan A'Hearn Finnish, Baltic average gas-fired power generation MW Apr-24 Apr-23 Mar-24 ± Apr 23 ± Mar 24 Estonia 5 6 7 -1 -2 Latvia 49 18 215 31 -166 Lithuania 46 47 52 -1 -6 Finland 205 230 277 -25 -72 Total 305 301 551 4 -246 — Entso-E Daily average minimum temperature in FinBalt capitals °C Apr-24 Apr-23 Mar-24 ± yr/yr ± m/m 2014-23 Apr avg Vilnius 5.22 3.83 0.93 1.39 4.29 2.63 Riga 5.01 4.98 1.93 0.03 3.08 3.65 Tallinn 2.00 1.46 -0.59 0.54 2.59 1.17 Helsinki 0.11 -0.45 -2.55 0.56 2.66 0.12 — Speedwell Finnish and Baltic April consumption by country GWh Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Japanese ethylene producers unite for decarbonization


24/05/08
24/05/08

Japanese ethylene producers unite for decarbonization

Tokyo, 8 May (Argus) — Japanese petrochemical producers Mitsui Chemicals, Mitsubishi Chemical and Asahi Kasei have agreed to co-operate on decarbonization of their ethylene crackers in west Japan, targeting to decide a pathway within the current April 2024-March 2025 fiscal year. They plan to accelerate carbon neutrality at Mitsubishi Chemical and Asahi Kasei's 496,000 t/yr Mizushima cracker in Okayama prefecture and Mitsui Chemicals' 455,000 t/yr Osaka cracker in Osaka prefecture. The partners aim to introduce biomass feedstocks such as biomass-based naphtha and bioethanol and low-carbon cracking fuels like ammonia, hydrogen and electricity. They said joining forces will enable them to accelerate reducing greenhouse gas emissions, although they have not yet decided any further details. Mitsui Chemicals has experience in using bio-naphtha and recycled pyrolysis oil at its Osaka cracker. Japanese petrochemical producers have increasingly united to achieve decarbonization of their production processes, which account for around 10pc of the Japanese industrial sector's carbon dioxide emissions, according to the trade and industry ministry. Mitsui Chemicals, Sumitomo Chemical and Maruzen Petrochemical agreed to study the feasibility of chemical recycling and using bio-feedstocks at the Keiyo industrial complex in Chiba. By Nanami Oki Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

New Zealand’s Genesis Energy to resume coal imports


24/05/08
24/05/08

New Zealand’s Genesis Energy to resume coal imports

Sydney, 8 May (Argus) — New Zealand's upstream firm and utility Genesis Energy plans to resume thermal coal imports later this year to feed its dual gas- and coal-fired Huntly power plant. The resumption was because of lower domestic gas production and rapidly declining coal stockpiles, and will mark the firm's first coal imports since 2022. Coal inventories at the 953MW Huntly plant, — New Zealand's largest power station by capacity and the country's only coal-fired facility — recently slipped below 500,000t, down from 624,000t at the end of March, and will fall below 350,000t by the end of the winter. This will trigger a need to purchase more coal to maintain a target operational stockpile of around 350,000t ahead of winters in 2025 and 2026, the company said on 8 May. Imports are currently the most efficient option for the quantity the company will need, with a delivery time of around three months, chief executive Malcolm Johns said. Genesis typically imports from Indonesia, the company told Argus . Gas production in New Zealand has dropped at a faster rate than expected, with major field production in April down by 33pc on the year, Genesis said. Lower gas availability typically leads to more coal burn, because the Huntly plant runs on gas and coal. This is in addition to an extended period of low hydropower inflows in recent months, which required higher thermal generation to ensure supply security. A prolonged outage at Huntly's unit 5 gas turbine between June 2023 and January 2024 also led to an even greater need for coal-fired generation, Genesis said. Biomass transition The company — which is 51pc owned by the state — is the second-largest power retailer in New Zealand, behind domestic utility Mercury, according to data from the Electricity Authority. It has a NZ$1.1bn ($659mn) programme for renewable power generation and grid-scale battery storage , which includes a potential replacement of coal with biomass at Huntly. But the transition to biomass "will take some years," Johns said. Genesis has successfully completed a biomass burn trial at Huntly last year and has collaboration agreements with potential New Zealand pellet suppliers, but there is currently no local source for the type of pellets needed for the plant. Genesis is hoping to move to formal agreements "as soon as counterparties are able". The company will not consider importing pellets, it told Argus . "We will only use biomass if we can secure a local New Zealand supply chain that is sustainable and cost-effective," it said. Domestic gas production New Zealand's three-party coalition government said separately on 8 May that the "material decline" in local gas production threatens energy security, blaming the previous Labour party-led government for "policy decisions which have disincentivised investment in gas production." The decisions — which were part of the former government's pledge to achieve a carbon-neutral economy by 2050 — led to a reduction in exploration for new gas resources since 2021, while suppressed maintenance drilling reduced production from existing gas fields, according to a joint release from energy minister Simeon Brown and resources minister Shane Jones. "Due to this significant reduction in gas production, the government has also been advised that some large gas consumers are expressing concern about their ability to secure gas contracts," the government said. Major industrial users such as Canada-based methanol producer Methanex have been forced to reduce production as a result, it noted. "We are working with the sector to increase production, and I will be introducing changes to the Crown Minerals Act to parliament this year that will revitalise the sector and increase production," Jones added. By Juan Weik Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Doubts abound over US midcon E15 shift: NATSO


24/05/07
24/05/07

Doubts abound over US midcon E15 shift: NATSO

Houston, 7 May (Argus) — An effort by eight US midcontinent states to start selling 15pc ethanol (E15) gasoline blends year-round starting in 2025 remains unlikely, according to US fuel retailer trade association NATSO. The US approved last month the request from Illinois, Iowa, Minnesota, Missouri, Nebraska, Ohio, South Dakota and Wisconsin for year-round E15 gasoline sales starting next year. But even with that approval there are many barriers to making those sales a reality, said David Fialkov vice president of government affairs for NATSO, which represents truck stops and travel center operators. This includes a lack of investment from pipelines and refiners to prepare for the changes, as well as the higher costs of separating and selling different gasoline specifications at the retail level. "I remain pessimistic that it will come to fruition," Fialkov said Tuesday at a conference held by fuel retail industry group SIGMA in Austin, Texas. Political pressure to delay or abate the change in the midcontinent states will probably continue until refiners, pipeline companies and retailers begin to make the investments necessary, said Fialkov. E15 has been available for sale across the US since 2019, but a federal court in 2021 found that the Clean Air Act offers a fuel volatility waiver to refiners to produce only 10pc ethanol gasoline. The Environmental Protection Agency (EPA) has worked around this ruling for the last two summers by issuing temporary emergency orders allowing the sale of E15 because of the war in Ukraine's squeeze on crude prices. A group of midcontinent refiners has petitioned the EPA to delay implementation of the E15 rule until the summer of 2026. The EPA has not yet ruled on the request. Fialkov said a legislative solution to the issue at the federal level would provide a clear and uniform pathway to E15, as opposed to the the EPA's rule which leaves some states still relying on the waiver and others opting to go with year-round E15. By Zach Appel Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

EPA sets new oil and gas methane reporting rules


24/05/07
24/05/07

EPA sets new oil and gas methane reporting rules

Washington, 7 May (Argus) — Federal regulators have updated emissions reporting requirements for oil and gas facilities as they prepare to implement a methane "waste" fee for the industry. The US Environmental Protection Agency (EPA) on Monday finalized new rules it says will improve the accuracy of data from the oil and gas sector under the federal greenhouse gas emissions reporting program. Oil and gas facility owners and operators will be required to estimate emissions from additional types of equipment under the rule, and they can draw on newer technologies, like remote sensing, to help estimate emissions. "EPA is applying the latest tools, cutting edge technology, and expertise to track and measure methane emissions from the oil and gas industry," agency administrator Michael Regan said. "Together, a combination of strong standards, good monitoring and reporting, and historic investments to cut methane pollution will ensure the US leads in the global transition to a clean energy economy." Data to support new fee The revisions to the "Subpart W" reporting requirements will be used to determine the amount of methane that will be subject to a "waste emissions charge" created by the Inflation Reduction Act. Under the law, the charge will be calculated based on the annual data that about 8,000 oil and gas sources are now required to report. The charge will begin at $900/t for 2024 methane emissions above a minimum threshold using current measurement data. It will then rise to $1,200/t in 2025 and $1,500/t in subsequent years. Industry officials had raised "serious concerns" about several aspects of the original proposal , warning it could lead to inflated emissions data. "We are reviewing the final rule and will work with Congress and the administration as we continue to reduce GHG emissions while producing the energy the world needs," American Petroleum Institute vice president of corporate policy Aaron Padilla said. The industry group previously said it will ask Congress to repeal the fee, which is only likely to occur if Republicans win control of the White House. Data collected since 2010 Oil and gas facilities have reported emissions under Subpart W since 2010. To simplify reporting, operators often count the equipment they have deployed, and use industry-wide averages to estimate emissions, in addition to other direct and indirect measurements. The industry has argued the Subpart W data is not accurate enough to collect the methane charge, which is expected to cost operators more than $6bn over the next decade. Environmental groups have had their own criticisms of the data, which they say omits vast amounts of emissions such as those from "super-emitter" events and poorly maintained flares. The final rule seeks to respond to some of those concerns by relying on updated emission factors, incorporating additional empirical data on emission rates, collecting data at a more granular level and relying on remote sensing technologies to detect large emission events. EPA also revised Subpart W to include more types of sources, including produced water tanks, nitrogen removal units and crankcase venting. The final rule also sets a threshold of 100 kg/hr of methane for requiring the reporting of emissions from "other large release events." The new data rules will take effect on 1 January 2025 and will first apply to reports submitted in early 2026 for next year's emissions. EPA is allowing the use of the new methodologies for calculating 2024 emissions, but operators can still use the existing rules. By Michael Ball Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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