Mexico revives Central America gas and power plan

  • Market: Electricity, Natural gas
  • 22/05/19

Mexico has revived an ambitious energy integration program connecting it with Guatemala, Honduras and El Salvador, part of President Andres Manuel Lopez Obrador's plan to increase development in those countries to keep northern migration in check.

A five-project plan presented this week during one of the president's daily press conferences aims to integrate Mexican power and natural gas with the northern triangle region in Central America.

"Power connection between Mexico and Central America needs to be consolidated," said by Alicia Barcena, executive secretary of the Economic Commission for Latin America and the Caribbean (ECLAC), which developed the plan.

The ECLAC plan would coincide with nearly $10bn/year in planned spending through 2030 by Mexico. Lopez Obrador said foreign relations minister Marcelo Ebrard would try to negotiate an agreement for such projects with all the countries, including the US.

Lopez Obrador has repeatedly called on transforming the US-driven Merida initiative — which was put forth a decade ago to combat organized crime and foster rule of law in Mexico. He has suggested funds could be routed to boost development in Central America instead of channeling funds for militarization and fighting organized crime.

"We do not want Plan Merida, we do not want armored helicopters," Lopez Obrador said. "We want cooperation for development because that is what will help us pacify Mexico and Central America and for there to be peace and justice with prosperity."

The ECLAC plan includes a $1.2bn, 300MW gas-fired power plant in Honduras fed by a gas terminal in Puerto Cortes, a $300mn power interconnection between Mexico and Guatemala, as well as public works between both countries to increase tourism. The plan also proposes a 710km (441 miles) rail line from Ciudad Hidalgo in Mexico's Chiapas state to ports in El Salvador that would build on pre-existing lines that run through Guatemala.

But the most ambitious project of the five presented yesterday is the 600km (373mi), $1bn Mexico-Guatemala natural gas pipeline, which last gained ground under a preliminary state-to-state agreement signed in April 2014. The pipeline project was part of an agreement signed between the administration of former US president Barrack Obama and the governments of Guatemala, Honduras and El Salvador, with backing from the Inter-American Development Bank.

The original pipeline plan begins in Salina Cruz, in the southern Mexican state of Oaxaca, crosses Chiapas and ends in Escuintla, in southern Guatemala. It is still unclear how much investment would be required for the line to reach Honduras and the planned 300MW power plant, but President Juan Orlando Hernandez said it would cost $700mn in 2015.

The natural gas volumes to Central America would potentially come from the US. Mexico imported some 6 Bcf/d of natural gas on average in 2018, of which over 80pc came from US cross-border pipelines, according to energy ministry Sener. Although an aggressive pipeline development plan during the previous Mexican administration brought gas infrastructure to states that lacked pipelines, there are still no gas lines in the southwest states of Oaxaca and Chiapas, which would be essential to deliver volumes to Guatemala.

Cooperation between Mexico and Guatemala has been thriving for years, with more than 40 bilateral agreements over shared power interests. Guatemala exported some 618.7GWh of power to Mexico in 2018, up from 104GWh exported in 2017 and a dramatic increase from just 27GWh in 2015, according to data from national power administrator Administrador del Mercado Mayorista (AMM).

Guatemala imported 742.5GWh from Mexico in 2018, down from 853GWh in 2017 but significantly up from 185.9GWh in 2013 per AMM data.


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
01/05/24

US Fed signals rates likely to stay high for longer

US Fed signals rates likely to stay high for longer

Houston, 1 May (Argus) — Federal Reserve policymakers signaled they are likely to hold rates higher for longer until they are confident inflation is slowing "sustainably" towards the 2pc target. The Federal Open Market Committee (FOMC) held the federal funds target rate unchanged at a 23-year high of 5.25-5.5pc, for the sixth consecutive meeting. This followed 11 rate increases from March 2022 through July 2023 that amounted to the most aggressive hiking campaign in four decades. "We don't think it would be appropriate to dial back our restrictive policy stance until we've gained greater confidence that inflation is moving down sustainably," Fed chair Jerome Powell told a press conference after the meeting. "It appears it'll take longer to reach the point of confidence that rate cuts will be in scope." In a statement the FOMC cited a lack of further progress towards the committee's 2pc inflation objective in recent months as part of the decision to hold the rate steady. Despite this, the FOMC said the risks to achieving its employment and inflation goals "have moved toward better balance over the past year," shifting prior language that said the goals "are moving into better balance." The decision to keep rates steady was widely expected. CME's FedWatch tool, which tracks fed funds futures trading, had assigned a 99pc probability to the Fed holding rates steady today while giving 58pc odds of rate declines beginning at the 7 November meeting. In March, Fed policymakers had signaled they believed three quarter points cuts were likely this year. Inflation has ticked up lately after falling from four-decade highs in mid-2022. The consumer price index inched back up to an annual 3.5pc in March after reaching a recent low of 3pc in June 2023. The employment cost index edged up in the first quarter to the highest in a year. At the same time, job growth, wages and demand have remained resilient. The Fed also said it would begin slowing the pace of reducing its balance sheet of Treasuries and other notes in June, partly to avoid stress in money markets. By Bob Willis Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Find out more
News

FERC OK’s Virginia Transco gasline expansion


01/05/24
News
01/05/24

FERC OK’s Virginia Transco gasline expansion

New York, 1 May (Argus) — The US Federal Energy Regulatory Commission (FERC) today gave Williams the green light to expand natural gas capacity to Virginia by 101mn cf/d (2.9mn m3/d) on its Transco pipeline. The project, called the Commonwealth Energy Connector, involves the construction of 6.3 miles of new pipeline within Transco's existing right-of-way in southeast Virginia, near the border with North Carolina. The project also includes adding horsepower at compressor station 168, west of the new pipeline segment. Williams plans to begin construction this winter and put the project into service by the end of 2025. Environmental advocacy group Sierra Club opposed the project, arguing FERC failed to assess its potential greenhouse gas emissions, rendering its National Environmental Policy Act analysis moot. FERC disagreed, conceding that although the project's final Environmental Impact Statement demonstrated it would contribute to greenhouse gas emissions, the effects of those emissions on the environment could not be measured because FERC lacks the methodology to do so. The US south-Atlantic gas market has become more volatile in recent years as gas and power demand have soared, outpacing pipeline capacity expansions in the region. The combined gas consumption of Virginia and North and South Carolina in 2022 averaged 4.7 Bcf/d, up by 69pc from a decade earlier, US Energy Information Administration data show. Regional gas and power consumption is widely expected to continue climbing through the end of the decade on a massive build-out of data centers , especially in Virginia. By Julian Hast Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

News

US gas industry pins hopes on AI power demand


01/05/24
News
01/05/24

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.

News

Mitsui makes delayed exit from Paiton power project


01/05/24
News
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.

News

Italian April power imports drop on NTC restrictions


30/04/24
News
30/04/24

Italian April power imports drop on NTC restrictions

London, 30 April (Argus) — Italian net electricity imports fell to their lowest in more than a year in April owing to significant constraints in net transfer capacity (NTC) from France to Italy, supporting an increase in domestic generation. Net imports averaged 4.7GW in April, down from 7GW in March and well below 6.7GW in the same month last year, according to data from Italian transmission system operator Terna. This was the country's tightest net importing position for any month since August. Italian imports from France saw the largest year-on-year decline, averaging 1.5GW compared with 2.7GW in April last year. This was Italy's lowest net imports since August 2022. Imports from Switzerland also fell on the year, declining by 500MW to 2.3GW, the lowest since August last year ( see chart ). The steep drop in imports to Italy's north zone is largely a result of significant reduction in the available NTC on France's eastern borders. Since early March, strong commercial exports through all of France's eastern borders, combined with low availability of the French power grid because of planned and unplanned outages, have led to "an extremely tense situation" for the French transmission system, the country's grid operator RTE has said. These factors have led to soaring physical flows and security issues on some interconnectors on the France-Switzerland and France-Italy borders. RTE on 5 March reduced the day-ahead NTC on the France-Italy border from a scheduled 4.5GW to 1.6GW, but the measure proved "insufficient to mitigate operational issues", RTE said. The overloads, although close to the France-Italy border, were induced by high commercial exports on all of France's eastern borders, including those with Belgium and Germany. RTE consequently applied additional safety measures to guarantee the operational security of the grid, such as lowering the NTC on the France-Switzerland border from 2.5GW to 2GW. Export constraints have resulted in French prices remaining at a significant discount to Italy, with the French spot index delivering at an average discount of €59.13/MWh in April compared with €35.37/MWh in March and €28.61/MWh in April last year. And falling Italian imports have driven a 2GW year-on-year increase in domestic generation to 24.6GW in April, while Italian power demand has remained virtually stable at 28.8GW. Minimum temperatures in Milan averaged 6.6°C on 1-30 April, up from 5.3°C in March and above 5.7°C in April last year. RTE is expecting some NTC curtailments until the beginning of May and from August to mid-October, it said. By Timothy Santonastaso Italian imports by country GW 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