Curacao to PdV: Fix refinery, pay debt by Dec

  • Spanish Market: Crude oil, Electricity, Oil products
  • 31/05/19

Dutch-controlled Curacao has informed Venezuela's national oil company PdV that it must return the 335,000 b/d Isla refinery in good condition and pay $26mn in debt for utility services before its operating lease expires in December.

The refinery should be "at least" in a "regular acceptable state of maintenance after so many years of operations, or better," the interim director of Curacao´s state-owned refinery company RdK, Marcelino de Lannoy, told Argus.

RdK says PdV has kept up with lease payments of $1.66mn per month but owes $26mn to local utility CRU for steam, water and electricity under a take-or-pay contract.

PdV has operated the refinery and associated Bullen Bay terminal under a long-term lease signed after Shell returned the facility to the local government in 1985.

Following at least two false starts, Curacao is again looking for a new refinery operator. One unnamed potential partner recently conducted a site visit, and a second one is scheduled to arrive in June, RdK says. Non-binding proposals are expected in July. Among the companies that previously eyed the facility is Saudi Aramco´s US refining unit Motiva.

In recent years the refinery has been mostly shut down on a lack of feedstock, maintenance and utility services, threatening 2,000 local jobs, while activity at the Bullen Bay terminal has slowed to a trickle.

In early May Curacao received a US Treasury license that would clear the way to contract a new partner for the refinery without running afoul of US sanctions on PdV.

The oil assets on Curacao are part of PdV´s once-bustling logistical network in the Dutch Caribbean. Activity has dwindled in part because the Dutch legal jurisdiction has facilitated the seizure of Venezuelan assets by a multitude of creditors in recent years.

Isla and PdV officials could not be reached for comment.

Curacao currently hosts an estimated 27,000 Venezuelan migrants, out of a population of 160,000, part of a region-wide refugee wave fueled by Venezuela's political and economic crisis. The Dutch government recently approved 24mn euros to help Curacao and nearby Aruba cope with the migration flow.


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01/05/24

Cenovus boosts oil sands output by 4pc in 1Q

Cenovus boosts oil sands output by 4pc in 1Q

Calgary, 1 May (Argus) — Canadian integrated Cenovus Energy increased its oil sands production by 4pc in the first quarter, led by gains at Lloydminster Thermal and Foster Creek heavy crude assets, and the company plans to boost output further to supply the newly opened Trans Mountain Expansion (TMX) pipeline. Cenovus pumped out 613,000 b/d of crude from its oil sands projects in Alberta, up from 588,000 b/d in the same quarter last year, the Calgary-based company reported on Wednesday. This was one of the highest producing quarters for Cenovus' oil sands assets since acquiring Husky in early 2021, second only to the 625,000 b/d produced in the fourth quarter that year. Cenovus has a commitment of about 144,000 b/d on the newly completed 590,000 b/d TMX pipeline, which was placed into service on Wednesday , and the company has plans to push upstream output higher over the next several years across its portfolio to meet its commitment. The pipeline nearly triples the amount of Canadian crude that can reach the Pacific coast without first having to go through the US. First-quarter production from the Lloydminster Thermal segment rose to 114,000 b/d, up from 99,000 b/d a year earlier, because of higher reliability, according to Cenovus. Cenovus' Foster Creek production rose to 196,000 b/d of bitumen, up from 190,000 b/d in first quarter 2023. The company plans to bring another 30,000 b/d online at the steam-assisted gravity drainage (SAGD) asset by the end of 2027 through optimization projects. To the north, Christina Lake's first-quarter bitumen output of 237,000 b/d was steady with previous quarters. The asset is expected to get a significant boost by the end of 2025 when a pipeline connecting the project to output from the neighbouring Narrows Lake asset is completed. The 17 kilometer (11 mile) Narrows Lake tie-back will add 20,000-30,000 b/d of bitumen to Christina Lake, which already ranks as the industry's largest SAGD project. The pipeline is 67pc complete and should be placed into service in early 2025, Cenovus executives said Wednesday on an earnings call. Northeast of Fort McMurray, Alberta, new well pads are planned at Sunrise in 2025, where Cenovus also plans to push production higher by 20,000 b/d. Sunrise produced an average of 49,000 b/d in the first quarter this year, up from 45,000 b/d in the same quarter 2023. Cenovus' output company-wide rose to 801,000 b/d of oil equivalent (boe/d) in the first quarter, up from 779,000 boe/d a year earlier. This includes oil sands, natural gas liquids, natural gas, conventional and offshore assets. Cenovus posted a profit of C$1.2bn ($871mn) in the quarter, up from a C$636mn profit during the same quarter of 2023. By Brett Holmes 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.

Tankers can take TMX crude mid-May: Trans Mountain


01/05/24
01/05/24

Tankers can take TMX crude mid-May: Trans Mountain

Calgary, 1 May (Argus) — Commercial operations for the 590,000 b/d Trans Mountain Expansion (TMX) crude pipeline in western Canada have officially started today, but tankers will not be able to load crude from the line until later this month. Line fill activities, which began on 16 April, are still ongoing for the C$34bn ($25bn) project that stretches from Edmonton, Alberta, to the docks in Burnaby, British Columbia. About 70pc of the volumes needed are in the 1,181 kilometre (733 mile) line, Trans Mountain said on Wednesday. "As of today, all deliveries for shippers will be subject to the Expanded System tariff and tolls, and tankers will be able to receive oil from Line 2 by mid-May," Trans Mountain said. Aframax-size crude tankers started to take position on the west coast last month in anticipation of the new line. But the inability to deliver crude at Burnaby, while still having to pay full tolls, was a concern raised by several shippers on 23 April. "Trans Mountain must be able to receive, transport and deliver a shipper's contract volume," the shippers said in a letter to the CER. The ability to deliver the crude is "clearly central and fundamental qualities of firm service." The CER in November approved interim tolls for the system that will further connect Albertan oil sands producers to Pacific Rim markets. Shippers will, at least initially, pay C$11.46/bl to move crude from Edmonton, Alberta, to the Westridge terminal in Burnaby, British Columbia. The fixed portion accounts for C$10.88/bl of this and has nearly doubled from a C$5.76/bl estimate in 2017. The Canada Energy Regulator (CER) on 30 April gave Trans Mountain a green light to put TMX into service , ending years of uncertainty that the project would ever be completed. The expansion project, or Line 2, nearly triples the capacity of Canadian crude that can flow to the Pacific coast, complementing the original 300,000 b/d line, or Line 1, that has been operating since 1953. By Brett Holmes 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.

Canada’s TMX pipeline ready to move crude: Update


30/04/24
30/04/24

Canada’s TMX pipeline ready to move crude: Update

Adds regulatory approvals received. Calgary, 30 April (Argus) — Canada's 590,000 b/d Trans Mountain Expansion (TMX) crude pipeline can now start moving volumes to the Pacific coast after receiving final regulatory approvals today, more than a decade after the project was first conceived. The Canada Energy Regulator (CER) approved Trans Mountain's final applications on Tuesday, giving the midstream company a green light to put its C$34bn ($25bn) project into service. Trans Mountain had recently maintained its commitment to being ready by 1 May. The expansion nearly triples the existing 300,000 b/d Trans Mountain line that runs from Edmonton, Alberta, to Burnaby, British Columbia. Also expanded was the Westridge Marine Terminal from one dock to three, all capable of loading Aframax-sized vessels. The line will provide Canadian oil sands producers with a significant export outlet without having to first go through the US. Much of the new volume to flow on TMX is expected to be heavy sour crude. Federally-owned Trans Mountain had submitted applications as recent as 15 April for the final section of the pipeline about 140 kilometers (87 miles) east of the line's terminus in Burnaby. The final applications concerned piping, valves and other components at two pipeline inspection device traps and the mainline pipe between the two traps. The traps were added for safety assurance when the operator was allowed by CER to use a smaller diameter pipe as part of the Mountain 3 deviation. Mountain 3 was the last segment of the pipeline to be constructed because of delays relating to difficult terrain while tunneling. The "golden weld" marking the end of construction occurred on 11 April, according to Trans Mountain. A group of shippers last week expressed concern that TMX would not be ready for commercial service by 1 May. The pipeline had been marred by legal challenges and cost over-runs since it was first proposed in 2013 by its then-owner US midstream firm Kinder Morgan. The Canadian government took ownership of it in 2018. By Brett Holmes Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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