EU Jan gas consumption highest in two years

  • Market: Natural gas
  • 04/03/24

EU gas consumption was up by around 9pc on the year in January and was the highest for any month since January 2022, preliminary data from Eurostat show.

Across the bloc's 27 member states, consumption was 8.8pc higher than in January last year, with demand up in all but two countries. Of the top five largest consumers — Germany, the Netherlands, Spain, Italy and France — consumption was up in the latter four, most significantly in the Netherlands by nearly 22pc.

Germany, the bloc's largest consumer, was the notable exception. Consumption fell by just over 2pc on the year, according to Eurostat data. But this directly contradicts numbers from market area manager Trading Hub Europe (THE), which show aggregate high and low-calorie demand growing by a significant 16pc. If only including high-calorie demand, THE data shows an even larger year-on-year increase of roughly 19pc.

It is unclear why there is such a large discrepancy between Eurostat and THE data, although Eurostat told Argus that German data is provided to them by the German national statistics office Destatis. Argus compared historical data from Destatis and THE, and found that they were broadly in line with each other, with THE data typically slightly higher than Destatis', apart from the notable exception of January 2023 (see THE vs Destatis graph). This could suggest that Destatis' January 2023 data is erroneously high, and therefore why German consumption is shown falling on the year in January 2024. Destatis has only publicly released data for gas consumption through to the end of 2023, so January numbers are not yet available.

German gas-fired power production rose significantly to 6.5TWh, from 5TWh in January 2023, data from Fraunhofer ISE show, and Argus estimates that industrial demand was roughly 5pc higher.

Across the rest of the EU, the largest proportional increases came in the Baltic states and Finland, where consumption soared in January as a result of a severe cold snap, which drove up gas demand for heating.

January consumption was also higher than in the preceding month across all countries, and was overall the highest for any month since January 2022. EU demand has been on an upward trajectory since August, rising in each consecutive month from September-January (see EU monthly demand graph).

EU gas-fired power generation was 16pc higher in January than in the previous year, as gas was firmly ahead of coal in the merit order.

But January was broadly mild across most of Europe, helping to keep consumption muted. While gas demand was up nearly 9pc on the year, it was down by 15pc from the 2017-21 January average, potentially reflecting some more permanent changes in consumer demand patterns. The European Commission last week proposed an extension of its member states' voluntary 15pc gas demand reduction commitments by another year to facilitate filling storage sites and because security of supply remains "delicate". The EU Council agreed on an extension of the measures on Monday.

THE vs Destatis 2022-23 consumption data GWh

Consumption change percentage by country Y-o-Y

Consumption change percentage by country M-o-M

EU27 gas consumption PJ

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

Mexican power outages enter fourth day

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.

Find out more
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

India's Chhara LNG terminal to start operations by Oct


10/05/24
News
10/05/24

India's Chhara LNG terminal to start operations by Oct

Mumbai, 10 May (Argus) — Indian state-run refiner Hindustan Petroleum (HPCL) will start up its 5mn t/yr Chhara LNG import terminal by October, a company official said in an investor call today. This follows commissioning delays after the firm faced difficulty in unloading its first cargo last month. The 160,000m³ Maran Gas Mystras vessel failed to unload at the terminal because of a "swell in the rough sea beyond permittable limit," the official added. The facility is set to be closed from 15 May-15 September because of the monsoon season. The firm will be ready to receive LNG cargoes from October as its pipeline that begins at the terminal and stretches over 40km to Gundala village in Gujarat is now complete, the official said. The pipeline is further connected to Gujarat State Petronet's city gas distribution network to Somnath district, a total stretch of 86.6km. The LNG vessel that arrived in mid-April at the terminal was left stranded for over a week as it could not achieve mooring mode after berthing, because of inclement weather and the lack of a breakwater facility at the terminal, a source close to the matter told Argus . Rough weather and sea conditions caused the vessel to hit the fenders, resulting in damage. Almost five loading arms were also broken before the whole operation was abandoned on 18 April, the source added. The fender acts as a buffer or cushion between the ship hull and the dock, and prevents damage as a result of contact between the two surfaces. HPCL is building a breakwater facility at the terminal which is required to ensure safe LNG tanker berthing during India's monsoon season. No specific timeline has been given for building the breakwater, but the terminal will be able to operate year-round once it is completed. Indian state-controlled refiner IOC brought in the distressed vessel through a tender seeking approximately 80mn m³ of regasified LNG for delivery to the 17.5mn t/yr Dahej terminal at around $8.40/mn Btu on a des equivalent. HPCL also has not awarded a tender that is seeking another early-May delivery cargo , which closed on 19 April. Commissioning of the Chhara LNG terminal has been delayed since September 2022 owing to pipeline issues. The terminal is the country's eighth LNG import facility, which would lift total regasification capacity to 52.7mn t/yr from 47.7mn t/yr currently. By Rituparna Ghosh Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

News

Korea's Kogas seeks short-term, long-term LNG from 2025


10/05/24
News
10/05/24

Korea's Kogas seeks short-term, long-term LNG from 2025

Singapore, 10 May (Argus) — South Korea's major importer Kogas is seeking short-term and long-term LNG through two separate tenders. The firm is seeking at least 700,000 t/yr of LNG for delivery over 2025-27, through a tender that will close on 3 June. Offers can be linked to a northeast Asian spot LNG price, Brent or Henry Hub. Kogas is also separately seeking 700,000 t/yr, 1.4mn t/yr or 2.1mn t/yr of LNG over a duration of 7-15 years, starting from 2027 or 2028. The firm is seeking offers on a fob or des basis, although it has specified a minimum vessel size of 135,000m³ for fob offers. Offers can be linked to either Brent or Henry Hub, and the deadline for submission is at 12am Korea time (3pm GMT) on 10 June. The firm's latest long-term requirement comes on the heels of another long-term agreement that it signed with BP just last month, for up to 9.8mn t of LNG over 11 years from mid-2026. This also comes after South Korea's trade, industry and energy ministry (Motie) announced on 2 May that Kogas will continue to seek new term import contracts for the super-chilled fuel, to stabilise prices and meet higher domestic gas demand. The renewed focus on securing term supply has come at an interesting time with spot LNG prices in a downward trend since late last year, right in the middle of the winter season when prices typically peak. The front half-month of the ANEA — the Argus assessment for spot LNG deliveries to northeast Asia — was last assessed at $10.165/mn Btu on 10 May, a drop of 40pc since prices peaked on 23 October 2023. More LNG importers are also seeking term volumes over 2025-27, which is widely deemed to be a period during which LNG supply could be tighter as it is just before the new US liquefaction capacity fully hits the market. Higher nuclear availability in South Korea over the upcoming northern hemisphere summer season could weigh on LNG demand over the season. The country may also further trim its LNG use in the years to come, as it increases its reliance on nuclear power generation. By Rou Urn Lee Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

News

Australia’s ANZ bank to end new gas, oil lending


09/05/24
News
09/05/24

Australia’s ANZ bank to end new gas, oil lending

Sydney, 9 May (Argus) — Australia-based bank ANZ has updated its oil and gas policy, with it to no longer provide direct financing to new or expanding upstream oil and gas projects. The bank declared its new policy as part of its 2024 half-year results released on 7 May, saying it would also decline to integrate new customers primarily focused on upstream oil and gas. ANZ said that while it believes gas plays a "material and important part in meeting Australia's current energy needs and will do so for the foreseeable future", it will instead collaborate with energy customers to help finance their transition away from fossil fuels. The bank has a 26pc greenhouse gas (GHG) emissions reduction by 2030 goal and committed in 2020 to exit all lending to companies with exposure to thermal coal, either through extraction or power generation by 2030 as part of lending criteria to support the 2015 UN Paris climate agreement target of net zero GHG emissions by 2050. ANZ has however promised to consider exceptions on a case-by-case basis, if any national energy security issues arise. Australia's banks have been under sustained pressure by environmental groups to exit lending to fossil fuel projects, as upstream gas firms also face shareholder rebellions over climate action plans. But Australia's federal government has conceded gas will likely be needed post-2050 as a firming power source for renewables and industrial feedstock for some sectors. But investment in upstream exploration has been extremely low in recent years, with imports of LNG likely in southern Australia from about 2026 to meet demand for industrial users and power generation. By Tom Major 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