Mexico to buy 13 power plants from Iberdrola

  • Spanish Market: Coal, Electricity, Natural gas
  • 04/04/23

The Mexican government signed a $6bn deal today to acquire 13 power generation plants from Iberdrola following ongoing disagreements that have impeded operations.

"This deal gives [state utility] CFE the majority share of the country's power generation … it is a new nationalization of the electricity industry," President Andres Manuel Lopez Obrador said today in a video to announce the deal.

The deal covers 8,539MW of power generation capacity, or 76pc of Iberdrola's current Mexico portfolio, including the Monterrey I and II, Altamira III, IV and V, Escobedo, La Laguna, Tamazunchale I, Baja California and Topolobampo II and III combined cycle plants. La Venta III wind farm operated under long-term power producer contracts with state power company CFE is also part of the deal.

The sale also covers the Monterrey III and IV, Tamazunchale II and Enertek combined-cycle plants that sell power to private-sector customers, according to an Iberdrola filing with the Spanish stock exchange.

The memorandum of understanding was signed between Iberdrola and Mexico Infrastructure Partners but Mexico's infrastructure investment fund, Fonadin, will provide the majority of the capital for the purchase, finance minister Rogelio de la O said.

Iberdrola has been the government's prime target in its discourse against private-sector companies that secured long-term power purchase contracts with CFE during the previous administration as well as self-supply permits that pre-date the 2014 energy reform, claiming they have unfairly gutted CFE's market share.

While government attempts to cancel the self-supply regime failed when congress voted against constitutional energy reform in April, Lopez Obrador has used energy authorities Cenace and CRE to squeeze independent power producers like Iberdrola.

Over the past two years, the CRE has denied Iberdrola's requests to amend power generation permits, attempted to impose a historic fine on the company for alleged fraudulent use of a self-supply permit and tapped the breaks on the launch of several new power plants.

Meanwhile, Cenace has periodically disconnected other Iberdrola plants from the grid despite protective injunctions secured by the independent power producer.

"We understand President Lopez Obrador's energy policy and have sought a solution that is good for the Mexican people and our shareholders," Iberdrola's president Ignacio Galan said today.

CFE will operate 13 of the plants to be acquired, increasing its market share to 55pc from 39pc, Lopez Obrador said.

"This will give CFE the critical mass it needs to lower power generation costs and to become, once again, the majority power generation company," he said.


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01/05/24

US gas industry pins hopes on AI power demand

US gas industry pins hopes on AI power demand

New York, 1 May (Argus) — US natural gas producers and pipelines have pivoted almost in unison this year to talking up what they see as one of the strongest bullish cases for gas this decade: surging electricity demand from yet-to-be-built data centers to power artificial intelligence software. EQT, the largest US gas producer by volume, in an investor presentation last week called growing data center demand the "cornerstone" to the "natural gas bull case." Combining its own research with data from the US Energy Information Administration, the gas giant forecast an increase in gas demand of 10 Bcf/d (283mn m3/d) by 2030 to generate electricity, mostly to run data centers. Its more aggressive data center build-out scenario envisions a whopping 18 Bcf/d increase in gas demand through 2030. Total US gas production is currently about 100 Bcf/d. Kinder Morgan, one of the largest US gas pipeline operators, this month forecast 20pc of US power being gobbled up by data centers in 2030, up from a 2.5pc share in 2022. Cobbling together projections from several consultancies and financial advisories, the company said the electricity needed to run artificial intelligence software alone will comprise 15pc of US power demand by 2030. If just 40pc of that demand is met by gas, that would represent an increase in gas demand of 7-10 Bcf/d, it said. This is roughly in line with the high end of US bank Tudor Pickering Holt's forecast for gas demand to power data centers through 2030 (1.3-8.5 Bcf/d) and well above Goldman Sachs' and consultancy Enverus' projections of 3.3 Bcf/d and 2 Bcf/d, respectively. New tech, old problems Separating the wide ranges of these projections is the highly speculative nature of forecasting demand years into the future for competing energy sources to power next-generation technology. But the major upside and downside risks, analysts say, concern the more humdrum challenges of permitting and building out energy infrastructure. Goldman Sachs expects 28GW, or 60pc, of the generation capacity needed to power new data centers through 2030 will come from natural gas — 9GW from combined cycle gas turbines and 19GW from gas peaker plants. But with an average lag of four years from the time a gas transmission project is announced to the time it enters service, to say nothing of the high probability of litigation being brought by environmentalists and landowners, construction and permitting timelines are "the most top of mind constraint for natural gas," the bank said. Indeed, litigation and opposition from state regulators have ultimately led developers to call off several interstate pipeline projects in the eastern US in recent years. The exception to the rule, Equitrans' 2 Bcf/d Mountain Valley Pipeline is moving forward only because congressional action allowed it to bypass federal permitting hurdles. This is a particular problem for the gas industry's hopes of exploiting the data center boom, as a large share of future data centers are slated to be built in the southeast US, far from the major US gas fields. New data centers representing 2 Bcf/d of gas demand in Georgia probably requires a new pipeline into the southeast, FactSet senior energy analyst Connor McLean said. Southeast premium A significant data-center buildout in the southeast without new pipelines could put upward pressure on regional gas prices, McLean said. This could exacerbate the effects of what has become perhaps the most prominent bullish case for US gas: a massive build-out of LNG export terminals along the US Gulf coast. With new export terminals pulling increasing volumes of gas south along the Transcontinental gas pipeline to super-chill and ship overseas in the coming years, the build-out in data centers will likely produce "an even bigger deficit in that southeast (gas) market," EQT chief financial officer Jeremy Knop told investors last week. "We think that market really, in time, becomes the most premium market in the country," he said. By Julian Hast Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

G7 coal exit goal puts focus on Germany, Japan and US


01/05/24
01/05/24

G7 coal exit goal puts focus on Germany, Japan and US

London, 1 May (Argus) — A G7 countries commitment to phase out "unabated coal power generation" by 2035 focuses attention on Germany, Japan and the US for charting a concrete coal-exit path, but provides some flexibility on timelines. The G7 commitment does not mark a departure from the previous course and provides a caveat by stating the unabated coal exit will take place by 2035 or "in a timeline consistent with keeping a limit of 1.5°C temperature rise within reach, in line with countries' net-zero pathways". The G7 countries are Italy — this year's host — Canada, France, Germany, Japan, the UK and the US. The EU is a non-enumerated member. The announcement calls for accelerating "efforts towards the phase-out of unabated coal power generation", but does not suggest policy action. It calls for reducing "as much as possible", providing room for manoeuvre to Germany, Japan and the US. Coal exports are not mentioned in the communique. Canada and the US are net coal exporters. France, which predominantly uses nuclear power in its generation mix is already scheduled to close its two remaining coal plants by the end of this year. The UK will shut its last coal-fired plant Ratcliffe in September . Italy has ended its emergency "coal maximisation plan" and has been less reliant on coal-fired generation, except in Sardinia . The country has 6GW of installed coal-fired power capacity, with state-controlled utility Enel operating 4.7GW of this. The operator said it wanted to shut all its coal-fired plants by 2027. Canada announced a coal exit by 2030 in 2016 and currently has 4.7GW of operational coal-fired capacity. In 2021-23, the country imported an average of 5.7mn t of coal each year, mainly from the US. Germany Germany has a legal obligation to shut down all its coal plants by 2038, but the country's nuclear fleet retirement in 2023, coupled with LNG shortages after Russia's invasion of Ukraine, led to an increase in coal use. Germany pushed for an informal target to phase out coal by 2030, but the grid regulator Bnetza's timeline still anticipates the last units going offline in 2038. The G7 agreement puts into questions how the country will treat its current reliance on coal as a backup fuel. The grid regulator requires "systematically relevant" coal plants to remain available as emergency power sources until the end of March 2031 . Germany generated 9.5TWh of electricity from hard-coal fired generation so far this year, according to European grid operator association Entso-E. Extending the current rate of generation, Germany's theoretical coal burn could reach about 8.8mn t. Japan Japan's operational coal capacity has increased since 2022, with over 3GW of new units connected to the grid, according to the latest analysis by Global Energy Monitor (GEM). Less than 5pc of Japan's operational coal fleet has a planned retirement year, and these comprise the oldest and least efficient plants. Coal capacity built in the last decade, following the Fukushima disaster, is unlikely to receive a retirement date without a country-wide policy that calls for a coal exit. Returning nuclear fleet capacity is curtailing any additional coal-fired generation in Japan , but it will have to build equivalent capacity to replace its 53GW of coal generation. And, according to IEA figures, Japan will only boost renewables up to 24pc until 2030. The US The US operates the third-largest coal-power generation fleet in the world, with 212GW operational capacity. Only 37pc of this capacity has a known retirement date before 2031. After 2031, the US will have to retire coal-fired capacity at a rate of 33GW/yr for four years to be able to meet the 2035 phase-out deadline. By Ashima Sharma Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Mitsui makes delayed exit from Paiton power project


01/05/24
01/05/24

Mitsui makes delayed exit from Paiton power project

Tokyo, 1 May (Argus) — Japanese trading house Mitsui completed on 30 April the ¥109bn ($690mn) sale of its stake in Indonesia's 2,045MW Paiton coal-fired power plant in east Java following multiple delays. Mitsui originally tried to complete its exit by the end of March 2022 . It said the procedures with Paiton's offtaker Indonesian state-owned power firm Persero took more time than expected without providing further details. Japanese thermal power producer Jera withdrew from Paiton by selling its 14pc share in 2021. Mitsui sold its 45.515pc share in Paiton Energy, as well as a 45.515pc stake in Netherlands-based subsidiary Minejesa Capital and a 65pc stake in Singapore-based IPM Asia that are related companies of the Paiton project. Mistui sold the stakes to RH International (RHIS), which is a Singapore-based subsidiary of Thai power producer Ratch, and Indonesian power company Medco Daya Abadi Lestari's subsidiary Medco Daya Energi Sentosa (MDES). Paiton Energy is now owned by RHIS, MDES and Qatar-based company Nebras Power. Mitsui did not disclose their ownership ratios. Paiton consists of the 615MW No.7, 615MW No.8 and the 815MW No.3 units, which sell electricity to Persero through an unspecified long-term contract. Mitsui now holds 9.6GW of power capacity assets globally, with 8pc being coal-fired projects. The exit from Paiton cut its coal-fired ratio by 8 percentage points, while raising its renewable ratio by 3 percentage points to 32pc. Growing global pressure against coal-fired power generation likely prompted Mitsui to exit Paiton. Energy ministers from G7 countries this week pledged to accelerate "efforts towards the phase-out of unabated coal power generation". By Nanami Oki Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

New US rule may let some shippers swap railroads


30/04/24
30/04/24

New US rule may let some shippers swap railroads

Washington, 30 April (Argus) — US rail regulators today issued a final rule designed to help customers switch railroads in cases of poor rail service, but it is already drawing mixed reviews. Reciprocal switching, which allows freight shippers or receivers captive to a single railroad to access to an alternate carrier, has been allowed under US Surface Transportation Board (STB) rules. But shippers had not used existing STB rules to petition for reciprocal switching in 35 years, prompting regulators to revise rules to encourage shippers to pursue switching while helping resolve service problems. "The rule adopted today has broken new ground in the effort to provide competitive options in an extraordinarily consolidated rail industry," said outgoing STB chairman Martin Oberman. The five-person board unanimously approved a rule that would allow the board to order a reciprocal switching agreement if a facility's rail service falls below specified levels. Orders would be for 3-5 years. "Given the repeated episodes of severe service deterioration in recent years, and the continuing impediments to robust and consistent rail service despite the recent improvements accomplished by Class I carriers, the board has chosen to focus on making reciprocal switching available to shippers who have suffered service problems over an extended period of time," Oberman said today. STB commissioner Robert Primus voted to approve the rule, but also said it did not go far enough. The rule adopted today is "unlikely to accomplish what the board set out to do" since it does not cover freight moving under contract, he said. "I am voting for the final rule because something is better than nothing," Primus said. But he said the rule also does nothing to address competition in the rail industry. The Association of American Railroads (AAR) is reviewing the 154-page final rule, but carriers have been historically opposed to reciprocal switching proposals. "Railroads have been clear about the risks of expanded switching and the resulting slippery slope toward unjustified market intervention," AAR said. But the trade group was pleased that STB rejected "previous proposals that amounted to open access," which is a broad term for proposals that call for railroads to allow other carriers to operate over their tracks. The American Short Line and Regional Railroad Association declined to comment but has indicated it does not expect the rule to have an appreciable impact on shortline traffic, service or operations. Today's rule has drawn mixed reactions from some shipper groups. The National Industrial Transportation League (NITL), which filed its own reciprocal switching proposal in 2011, said it was encouraged by the collection of service metrics required under the rule. But "it is disheartened by its narrow scope as it does not appear to apply to the vast majority of freight rail traffic that moves under contracts or is subject to commodity exemptions," said NITL executive director Nancy O'Liddy, noting it was a departure from the group's original petition which sought switching as a way to facilitate railroad economic competitiveness. The Chlorine Institute said, in its initial analysis, that it does not "see significant benefit for our shipper members since it excludes contract traffic which covers the vast majority of chlorine and other relevant chemical shipments." By Abby Caplan Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Italian April power imports drop on NTC restrictions


30/04/24
30/04/24

Italian April power imports drop on NTC restrictions

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