QP to take 100pc ownership of Qatargas 1

  • Spanish Market: Natural gas
  • 30/03/21

State-owned Qatar Petroleum (QP) will become the sole owner of the Qatargas 1 LNG project from the start of next year, after opting not to renew its joint venture agreement with foreign partners.

Since its establishment in 1984, Qatargas 1 has been a joint venture between QP with a majority 65pc stake, Total and ExxonMobil with 10pc each, and the Japanese duo of Marubeni and Mitsui with 7.5pc each. It consists of three LNG trains with a total capacity of around 10mn t/yr.

"The takeover by Qatar Petroleum will conclude more than 25 years of successful operations ... from which the first ever Qatari LNG cargo was exported," QP chief executive Saad Sherida al-Kaabi said.

The Qatargas 1 facilities will continue to be operated by Qatargas on QP's behalf. The move to take full ownership comes as QP forges ahead with the expansion of its 77mn t/yr Ras Laffan gas liquefaction complex. The first phase will see liquefaction capacity rise to 110mn t/yr by 2025 through the addition of four trains.

First gas from the North Field East (NFE) project, which will feed the new trains, is expected in the fourth quarter of 2025. In February, QP awarded a $13bn contract to a joint venture of Japan's Chiyoda and France's Technip for new onshore facilities as part of the first phase expansion.

In the second phase, QP plans to increase Qatar's total liquefaction capacity to 126mn t/yr by 2027 by developing the North Field South (NFS) project. And al-Kaabi said late last year that there could be potential for further expansion beyond that in the future. "As history has shown, we don't expect to stop at 126mn t/yr," he said at the time. "We continue to strive to develop our natural gas resources and lead the way in the world's LNG value chain."


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02/05/24

Shell's 1Q profit supported by LNG and refining

Shell's 1Q profit supported by LNG and refining

London, 2 May (Argus) — Shell delivered a better-than-expected profit for the first quarter of 2024, helped by a strong performance from its LNG and oil product businesses. The company reported profit of $7.4bn for January-March, up sharply from an impairment-hit $474mn in the previous three months but down from $8.7bn in the first quarter of 2023. Adjusted for inventory valuation effects and one-off items, Shell's profit came in at $7.7bn, 6pc ahead of the preceding three months and above analysts' estimates of $6.3bn-$6.5bn, although it was 20pc lower than the first quarter of 2023 when gas prices were higher. Shell's oil and gas production increased by 3pc on the quarter in January-March and was broadly flat compared with a year earlier at 2.91mn b/d of oil equivalent (boe/d). For the current quarter, Shell expects production in a range of 2.55mn-2.81mn boe/d, reflecting the effect of scheduled maintenance across its portfolio. The company's Integrated Gas segment delivered a profit of $2.76bn in the first quarter, up from $1.73bn in the previous three months and $2.41bn a year earlier. The segment benefited from increased LNG volumes — 7.58mn t compared to 7.06mn t in the previous quarter and 7.19mn t a year earlier — as well as favourable deferred tax movements and lower operating expenses. For the current quarter, Shell expects to produce 6.8mn-7.4mn t of LNG. In the downstream, the company's Chemicals and Products segment swung to a profit of $1.16bn during the quarter from an impairment-driven loss of $1.83bn in the previous three months, supported by a strong contribution from oil trading operations and higher refining margins driven by greater utilisation of its refineries and global supply disruptions. Shell's refinery throughput increased to 1.43mn b/d in the first quarter from 1.32mn b/d in fourth quarter of last year and 1.41mn b/d in January-March 2023. Shell has maintained its quarterly dividend at $0.344/share. It also said it has completed the $3.5bn programme of share repurchases that it announced at its previous set of results and plans to buy back another $3.5bn of its shares before the company's next quarterly results announcement. The company said it expects its capital spending for the year to be within a $22bn-$25bn range. By Jon Mainwaring Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

US Fed signals rates likely to stay high for longer


01/05/24
01/05/24

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.

FERC OK’s Virginia Transco gasline expansion


01/05/24
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.

US gas industry pins hopes on AI power demand


01/05/24
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.

Milei's bid to open Argentina's economy passes


30/04/24
30/04/24

Milei's bid to open Argentina's economy passes

Montevideo, 30 April (Argus) — Argentina's congress today approved the government's sweeping economic legislation that could open the door to more private-sector investment in energy and commodities. The bill passed on a 142-106 vote, with five abstentions, after a marathon 20-hour debate. Changes include privatizing some state-owned companies, controversial labor reforms and measures to promote LNG development. The omnibus legislation, which includes 279 articles, is an important victory for President Javier Milei's administration and will change the way many sectors, including energy, operate in the country. Lawmakers aligned with Milei's Liberty Advances party swiftly moved to the second stage of the process, which requires approval of individual articles. The omnibus bill was initially approved in February, but the administration withdrew it after congress failed to approve several key individual articles. That original version included 664 articles. Several of the more controversial articles were brought up immediately after the blanket approval and easily passed. They included an article allowing for privatization of state-run enterprises — national power company Enarsa is on the list — and another delegating to the administration the power to eliminate state agencies without having to consult with congress. Also approved was the article on labor reform. The country's oilseed industry and port workers' unions called a strike the previous day to pressure congress to modify the labor reform. That did not happen. It passed in a separate 136-113 vote. The strike started to fizzle with approval of the legislation. Approval of the package includes several articles the administration says will open the door to major investments in the energy sector. Chapter II specifically covers natural gas, and introduces new regulations for LNG. The chapter includes five articles that allow for 30-year contracts for LNG export projects and guarantees that gas supply cannot be interrupted for any reason. The energy secretariat has six months to design the implementing rules for LNG. The government wants to speed up monetization of the Vaca Muerta unconventional play, which has an estimated 308 trillion cf of natural gas reserves. It is pushing for Malaysia's Petronas to fully commit to a large-scale LNG facility that would start with a $10bn investment. Chapter IX of the legislation creates a new framework, known as the Rigi, for investments above $200mn. It offers tax, fiscal and customs benefits. Companies have two years from implementation of the legislation to take advantage of the Rigi. The chapter on this framework is one of the most complex in the bill, including 56 articles. It includes specific references to energy projects, from power generation to unconventional oil and gas development. The administration claims the legislation will help tame inflation and stabilize the economy. Inflation was 276pc annualized through February, but is declining, and Milei announced that monthly inflation would be in single digits when the March numbers are announced. The country recorded a 0.2pc quarterly fiscal surplus in the first quarter of this year, something not achieved since 2008. By Lucien Chauvin Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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