G7 makes exception for funding of overseas gas projects

  • Spanish Market: Coal, Natural gas
  • 28/06/22

Leaders of the G7 major economies have added a caveat to their commitment to end new direct international public financing for unabated fossil fuels by the end of this year, saying "publicly supported investment in the gas sector can be appropriate" in order to reduce dependency on Russian gas.

The group's climate and environment ministers in May committed to end new direct international public financing for unabated fossil fuels by the end of this year, "except in limited circumstances clearly defined by each country consistent with a 1.5°C warming limit and the goals of the Paris Agreement". The G7 nations are Canada, France, Germany, Italy, Japan, the UK and the US.

The pledge followed a similar commitment made by 39 countries and financial institutions — including Canada, France, Germany, Italy, the UK and US — on the sidelines of the UN Cop 26 climate conference in Glasgow last year, but which Japan had not signed.

In a communique issued today to mark the end of a two-day summit in Germany, the G7 countries said limited circumstances include investments in the LNG and the gas sector in the context of the phase-out of countries' dependency on Russian gas.

"We stress the important role increased deliveries of LNG can play, and acknowledge that investment in this sector is necessary in response to the current crisis," the G7 leaders said.

The communique said "publicly supported investment in the gas sector can be appropriate as a temporary response", but must be consistent with the countries' climate objectives and must avoid "creating lock-in effects".

Environmental campaign group Oil Change International said today's statement is putting at risk the opportunity to shift at least $33bn a year in international fossil fuel investments from the G7 governments towards clean energy. It said renewable energy and efficiency solutions can be deployed faster than new gas projects and better serve energy needs. Clean energy projects do not come with the stranded assets and financial stability risks of fossil gas, it said.

Observers expected commitments to end international financing of unabated fossil fuel projects made by the G7 ministers in May and at Cop 26 last November to take a hit on energy security concerns, especially because of the uncertainty over gas deliveries from Russia.

Soon after the G7 May ministerial meeting, Japan said it could continue financing upstream oil and gas projects despite its G7 pledge, according to Oil Change International. Germany also indicated it would pursue gas projects in Senegal.


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.

06/05/24

US majors widen output gap over European rivals

US majors widen output gap over European rivals

New York, 6 May (Argus) — ExxonMobil and Chevron are seeing investments in Guyana and the Permian shale basin pay off, widening a gap with their transatlantic counterparts that could get even bigger with the completion of recent mega-deals. ExxonMobil is championing a speedy ramp-up of a massive offshore oil discovery in Guyana, where production has surged to more than 600,000 b/d of oil equivalent (boe/d) in the space of just a few years. And Chevron recorded a 35pc jump in first-quarter US output from a year earlier, buoyed by better-than-expected performance from the Permian basin, as well as the $7.6bn acquisition of US independent PDC Energy that bolstered its footprint in Colorado's DJ basin. And after years of delays and cost overruns, its highly vaunted expansion project in Kazakhstan is finally close to seeing the light of day. Even though European rivals including Shell and BP are backtracking on previous plans to scale back their reliance on oil and gas production, the US majors are poised to extend their lead after dominating a recent round of industry consolidation. ExxonMobil will become the top producer in the Permian after wrapping up its $59bn takeover of shale giant Pioneer Natural Resources. Anti-trust regulators at the US Federal Trade Commission cleared the deal after barring Pioneer's former chief executive, Scott Sheffield, from gaining a seat on the board, following allegations that he sought to collude with Opec members. And Chevron is still optimistic that its pending $53bn purchase of independent producer Hess will close by the end of the year, even though ExxonMobil has thrown a spanner in the works by claiming its right of first refusal over Hess' 30pc stake in Guyana's prolific Stabroek block, where it is the operator. Chevron's attempt to muscle in on Guyana's oil riches would answer lingering concerns over its long-term growth profile. The dispute has now been referred to international arbitration in Paris and the company hopes the transaction can be completed this year. A failure of the deal to close would not "materially" hit Chevron's near-term valuation, according to bank HSBC. "However, the strategic gap between Chevron and ExxonMobil could widen over time if the Hess deal does not happen," the bank says. Advantage Exxon Excluding the Pioneer transaction, ExxonMobil forecasts its output will grow to 4.2mn boe/d by 2027 from about 3.8mn boe/d this year. Chief executive Darren Woods has doubled down on so-called "advantaged" projects including Guyana and the Permian, which offer the most profitable and low-cost barrels that will be key drivers of revenue growth. The company's share of overall production from such assets has increased to 44pc from 28pc in recent years. Woods sees the growing cash flow from those projects as vindication of his strategy to direct "counter-cyclical" investments before and during the pandemic, which were unpopular with some investors at the time. Spending discipline remains a key priority even as new projects start up. ExxonMobil has achieved $10.1bn of cost savings from 2019 levels, and is on course to hit $15bn by 2027. And Woods says there is scope for even more savings to be found. Meanwhile, Chevron says its output from the Permian is trending better than previous guidance for a 2-4pc decline in the first half of 2024, with more wells due to come on line later this year. The company is also preparing to start up its Anchor offshore platform in the Gulf of Mexico in the middle of the year, with more projects in the region to follow. "The outlook in the US is especially strong," chief executive Mike Wirth says. Chevron is guiding for 4-7pc overall output growth this year, after pumping a record 3.1mn boe/d last year. By Stephen Cunningham Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Indonesia’s MBAP sets lower coal output target for 2024


06/05/24
06/05/24

Indonesia’s MBAP sets lower coal output target for 2024

Manila, 6 May (Argus) — Indonesian coal producer Mitrabara Adiperdana (MBAP) has set a lower output target of 2.01mn t for 2024, to focus on developing its mining infrastructure. MBAP plans to improve its mining infrastructure to prepare for higher output in the next two years. It has earmarked $57.8mn for its capital expenditure this year, 49pc of which will be used for infrastructure development. This investment will allow MBAP to increase its output to 2.45mn t/yr in 2025-26, in line with its approved RKAB work plans. The firm aims to produce 2.01mn t in 2024, down by nearly 4pc from its 2023 output. The Indonesian Ministry of Energy and Mineral Resources (ESDM) has approved MBAP's target. But MBAP hopes to sell 2.3mn t of coal in 2024, up from 2.13mn t a year earlier, with sales including deliveries by its coal trading arm. Exports accounted for 73pc of the firm's total sales in 2023 and is expected to remain steady at 72-75pc this year. South Korea is expected to remain MBAP's largest market, with the country accounting for 29pc of total sales in 2023. But sales to China, which were at 18pc last year, are expected to increase this year. By Antonio delos Reyes Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

India’s Adani Power raises imported coal use in Jan-Mar


06/05/24
06/05/24

India’s Adani Power raises imported coal use in Jan-Mar

Singapore, 6 May (Argus) — India's leading private sector utility Adani Power more than doubled its use of imported thermal coal during January-March and in the April 2023-March 2024 fiscal year to meet rising power demand. The Bombay Stock Exchange-listed firm used 5.19mn t of imported coal over January-March, more than twice that of 1.99mn t a year earlier. Domestic coal burn also rose by nearly 18pc on the year to 8.83mn t during January-March, following higher availability of local fuel and increased dispatches to utilities. Adani Power consumed 19.44mn t of imported coal over India's April 2023-March 2024 fiscal year. This was also more than double that of 7.66mn t in 2022-23. Its domestic coal burn increased by 10pc on the year to 31.72mn t in 2023-24. Higher imports came on the back of a sharp drop in seaborne prices. The Argus -assessed Indonesian GAR 4,200 kcal/kg coal averaged $57.88/t fob Kalimantan over April 2023-March 2024, down by over 31pc from an average of $84.45/t in the year earlier. The company's fuel cost stood at 3.33 rupees/kWh sold (0.04¢/kWh sold) in January-March, down from Rs5.30/kWh sold a year earlier because of lower blended fuel costs, following a decline in seaborne coal prices. Fuel cost for 2023-24 stood at Rs3.59/kWh compared with Rs4.78/kWh in the previous year. Lower imported coal prices also boosted power offtake under imported coal-based power purchase agreements. The company sold 22.13bn units of electricity in January-March, up significantly from 14.25bn units sold a year earlier. It sold 79.27bn units in 2023-24, up from 53.39bn units in the year earlier. Higher volumes during January-March and the fiscal year were driven by its Mundra, Udupi, Raipur, and Mahan plants — apart from the incremental contribution of the Godda unit — which were commissioned in April 2023. Domestic power sales volumes were driven by growing power demand across the country, the company said. Utility demand could continue to support imports by utilities and lift overall Indian demand for seaborne coal. India imported 14.27mn t of thermal coal in March, up by 8pc from 13.2mn t a year earlier, according to shipping broker Interocean data. Thermal power expansion plans Adani Power operates 15.25GW of thermal generation capacity in the Gujarat and Maharashtra states of west India, Madhya Pradesh and Chhattisgarh in central India, Rajasthan in north India, Karnataka in south India and Jharkhand in eastern India. The firm is eyeing a capacity of more than 24GW by 2029. It is undertaking a brownfield thermal capacity expansion of 1.6GW at its 1.2GW Mahan power project in Madhya Pradesh. It has started developing a 1.6GW expansion at its existing 600MW unit in Chhattisgarh. Adani Power has also emerged as the frontrunner to acquire thermal generation capacity and an under-construction project from domestic debt-ridden Lanco Amarkantak Power. Lanco owned and operated a 600MW thermal power plant in central India's Chhattisgarh state and was planning 1.32GW of generating capacity under the second phase of the project. Adani is in the process of acquiring a 1.2GW debt-ridden thermal power project in south India's Tamil Nadu state. Plant operator Coastal Energen is also having a corporate resolution insolvency process. It is evaluating an organic expansion of 1.6GW, besides considering other inorganic acquisition opportunities, to meet strong demand for thermal power in the coming years, the company said. By Ajay Modi Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Brazil hydroelectric dam bursts under record rains


03/05/24
03/05/24

Brazil hydroelectric dam bursts under record rains

Sao Paulo, 3 May (Argus) — Brazilian power generation company Companhia Energetica Rio das Antas (Ceran) found a partial rupture in its 100MW 14 de Julho hydroelectric plant following record precipitation in Rio Grande do Sul state. Flooding from the record rains has left 37 dead and forced more than 23,000 people out of their homes, causing widespread damage across the state, including washed out bridges and roads across several cities. Ceran reported that the dam of the hydroelectric plant on the Antas River suffered a rupture under the heavy rains and the company implemented an emergency evacuation plan on 1 May. Ceran's 130MW Monte Claro and 130MW Castro Alves plants are under intense monitoring, the company said in a statement. Rio Grande do Sul state governor Eduardo Leite declared a state of emergency and the federal government promised to release funding for emergency disaster relief. Leite said the flooding will likely go down as the worst environmental disaster in the state's history. Brazil's southernmost state along the border with Argentina has been punished by record precipitation over the past year owing to the effects of the strong El Nino weather phenomenon, according to Rio Grande do Sul-based weather forecaster MetSul Meteorologia. Brazilian power company CPFL Energia controls Ceran with a 65pc equity stake. Energy company CEEE-GT, which is owned by steel manufacturer CSN, owns another 30pc, and Norway's Statkraft owns the remaining 5pc. The state had declared a state of emergency as recently as September 2023 because of unusually heavy rains that resulted in the death of more than 30 people. Weather forecasters expect El Nino conditions to abate in the coming months over the eastern Pacific. Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Chevron’s oily DJ basin buy boosts gas output


03/05/24
03/05/24

Chevron’s oily DJ basin buy boosts gas output

New York, 3 May (Argus) — Chevron's US natural gas production has surged in recent quarters due to its crude-focused acquisition of Denver-based PDC Energy last August, increasing the oil major's exposure to the US gas market months after that market entered an extended price slump. Chevron's US gas production in the first quarter was 2.7 Bcf/d (76mn m3/d), up by 53pc from the year-earlier quarter and the highest since at least 2021, according to company production data. Chevron's total US output rose by 35pc year-over-year to 1.57 b/d of oil equivalent (boe/d), while US crude output increased by 21pc to 779,000 b/d. The acreage Chevron picked up last year in the DJ basin of northeast Colorado and southeast Wyoming has higher gas-oil ratios than the rest of its US portfolio. Chevron mostly focuses US production in the crude-rich Permian basin of west Texas and southeast New Mexico. Since Chevron closed its acquisition of PDC on 7 August, US gas prices have mostly languished in loss-making territory. Prompt-month Nymex gas settlements at the US benchmark Henry Hub from 7 August 2023 to 2 May 2024 averaged $2.46/mmBtu, down from an average of $4.999/mmBtu in the year-earlier period. In a May 2023 conference call over Chevron's acquisition of PDC, chief executive Mike Wirth expressed optimism for the long-run outlook for natural gas, despite the more immediately dim outlook. "There's going to be stronger global demand for gas growth than there will be for oil over the next decade and beyond as the world looks to decarbonize," Wirth said. Despite lower US gas prices, Chevron has captured $600mn in cost savings from the PDC acquisition between capital and operational expenditures, the company told Argus . Crude prices have also been more resilient. Chevron's profit in the first quarter was $5.5bn, down from $6.6bn in the year-earlier quarter, partly due to lower gas prices. US gas prices have been lower this year as unseasonably warm winter weather and resilient production have created an oversupplied US gas market. A government report Thursday showed US gas inventories up by 35pc from the five-year average. By Julian Hast 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