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Europe should invest more in African energy: Ministers

  • Market: Natural gas
  • 06/09/22

Europe should significantly back investment in gas and provide a policy framework that enables European banks to invest in hydrocarbons across Africa, the Ghanaian and Nigerian energy ministers said on Tuesday at the Gastech conference in Milan.

Focusing on gas production in Africa is "a no-brainer", Nigerian oil minister Timipre Sylva said, with 600mn people living without electricity in Africa and 740 trillion ft³ (21 trillion m³) of gas reserves on the continent. Increased gas production would also help the continent's 900mn people who live without access to clean cooking fuels, provide massive job opportunities and allow the emergence of a new alternative supplier for Europe, a "win-win for Europe and Africa", the minister said.

And it is in Europe's own interest "to reduce discriminatory investment rules that the banks are doing", Sylva said. The minister said that he had previously told European officials that they "must provide the appropriate policy framework for your banks, so that they can invest in oil and gas".

The EU's energy taxonomy, set to come into force in January 2023, is a voluntary tool and a signpost for private investors towards climate neutrality. But investment from large European banks in oil and gas fell in 2021, unlike their north American counterparts.

Ghanaian minister Matthew Opoku Prempeh also called for more investment. "Africa has been chronically under-invested," he said. "No country should be told to stay where it is," he added.

The issue of European investment in African hydrocarbons had previously risen to the fore during European Commission president Ursula von Der Leyen's visit to Senegal in February. Senegalese President Macky Sall said that cutting off funding for new gas exploration would be a "fatal blow" for emerging African countries.

Indian minister welcomes change in narrative

Indian oil and gas minister Hardeep Singh Puri welcomed the shift in the popular narrative away from the "ideological hang-up about not using or not extracting the gas reserves you have".

"Gas is a clean fuel, if you have it why don't you use it," he said. He added that it is time to "step on the gas on all the plants, whether it is wind, solar, innovations, compressed biogas".


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07/10/24

CNRL to buy Chevron's Canadian oil sands, shale: Update

CNRL to buy Chevron's Canadian oil sands, shale: Update

New York, 7 October (Argus) — Canadian Natural Resources (CNRL) agreed to buy a 20pc stake in the Athabasca Oil Sands Project (AOSP) and 70pc interest in the Duvernay shale from Chevron for $6.5bn, extending its lead as Canada's top producer. The all-cash transaction has an effective date retroactive to 1 September, the companies said Monday. Closing is expected during the fourth quarter. The assets being sold accounted for about 84,000 b/d of oil equivalent (boe/d) of production, net of royalties, to Chevron last year. Chevron last October announced plans to acquire US independent Hess for $53bn, pledging to sell $10bn-$15bn of assets by 2028. While the Hess deal has been delayed by a mid-2025 arbitration hearing, Chevron, the second-largest US oil producer, has increasingly focused its attention on the Permian shale basin of west Texas and southeastern New Mexico, as well as an expansion project in Kazakhstan. CNRL's acquisition bolsters its position as Canada's largest petroleum producer after pumping out 1.29mn boe/d of oil and gas in the second quarter this year. About 72pc came from oil and natural gas liquids (NGLs), with the balance from natural gas. CNRL anticipates the oil sands and Duvernay assets will lift the company's production profile by about 122,500 boe/d in 2025. About half, or 62,500 b/d, will come in the form of synthetic crude oil produced from AOSP's 320,000 b/d Scotford upgrader near Edmonton, Alberta. The upgrader is fed diluted bitumen piped from the Muskeg River and Jackpine mines in the oil sands region. The deal would increase CNRL's stake in AOSP to 90pc. Calgary-based CNRL first made its foray into AOSP in 2017 when it bought a 70pc stake from Shell and Marathon Oil Canada for $9.75bn ($C$12.74bn). Muskeg River and Jackpine are adjacent to the company's fully owned Horizon mine and upgrader, and the increase in ownership may allow for increased synergies between the two assets, according to executives. "It allows for a little bit more ease in terms of governance on the asset," CNRL president Scott Stauth said Monday on an investor call. "I can see us utilizing the equipment more effectively between the two sites." Undeveloped oil sands projects Also included in Monday's deal are additional stakes in undeveloped oil sands leases that CNRL could tap as it works through its reserves. This includes a 20pc increase the Pierre River project that would provide CNRL with 90pc ownership; a 60pc increase in the Ells River project that would lift the company's stake to 90pc; a 33pc increase in the Saleski project, for 83pc; and a 6pc working interest in Namur that would reach 65pc. Reserves from Pierre River could be used to extend the life of the Horizon project as the North Mine depletes. A standalone facility there is also possible, but would require a significant capital outlay, CNRL executives said. CNRL in May said it was considering a massive 195,000 b/d increase to its Horizon production using two new technologies. CNRL said production from the light oil and liquids rich assets in the Duvernay is expected to average 60,000 boe/d in 2025, half of which would be natural gas. CNRL anticipates pushing production to 70,000 boe/d by 2027 with more than 340 locations already identified as candidates for drilling. With WTI above $70/bl, "this is a very attractive acquisition for us," CNRL chief financial officer Mark Stainthorpe said. CNRL has been actively acquiring assets in recent years. The company purchased Canadian assets belonging to Painted Pony in 2020, Devon Energy in 2019, TotalEnergies in 2018 and Cenovus Energy in 2017, among other deals. By Stephen Cunningham and Brett Holmes Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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Chevron shuts Gulf platform ahead of Hurricane Milton


07/10/24
News
07/10/24

Chevron shuts Gulf platform ahead of Hurricane Milton

New York, 7 October (Argus) — Chevron evacuated and shut in its Blind Faith oil and gas production platform in the Gulf of Mexico in advance of Hurricane Milton, which has strengthened into a category 5 storm as it barrels toward Florida's west coast. Output from Chevron's other operated facilities in the region remains at normal levels, the company said today. The 65,000 b/d Blind Faith platform is located around 160 miles southeast of New Orleans. Milton, with maximum sustained winds of 160 mph, was about out 130 miles west of Progreso, Mexico, according to an 11am ET National Hurricane Center advisory. The storm will move through the Campeche Bank offshore region north of Mexico's Yucatan peninsula — where state-owned Pemex's largest oil and natural gas production operations are located — today and Tuesday, then cross the eastern Gulf of Mexico and approach the west coast of the Florida Peninsula by Wednesday. On its current track, the hurricane is expected to skirt to the south of the majority of US offshore oil and natural gas platforms in the Gulf of Mexico. The region accounts for around 15pc of total US crude output and 5pc of US natural gas production. Hurricane Helene temporarily shut in up to 29pc of oil production and 20pc of gas output in the Gulf of Mexico late last month. By Stephen Cunningham Hurricane Milton projected path Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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Global bio-bunker demand to pick up, US left behind


04/10/24
News
04/10/24

Global bio-bunker demand to pick up, US left behind

New York, 4 October (Argus) — Tightening vessel carbon intensity indicator (CII) scores and looming 2025 FuelEU marine regulation are expected to raise biodiesel demand for bunkering, but non-competitive US prices should continue to weigh down on US bio-bunker demand. Houston B30, a blend of used cooking methyl ester (Ucome) and very low-sulphur fuel oil (VLSFO), in September averaged at $821/t, a $45/t premium to B30 sold in Amsterdam-Rotterdam-Antwerp, and a $55/t premium to B24 sold in the west Mediterranean hub of Gibraltar and Algeciras (see chart) . Houston B30 was also priced at $115/t and $61/t premium to B24 sold in Singapore and Guangzhou, China, respectively. The price premium would continue to incentivize ship owners with global, ocean-going fleets to pick Asia first for their biodiesel bunker purchases, followed by northwest Europe and western Mediterranean. US demand for biodiesel for bunkering would continue to stagnate unless the US passes a legislation allowing Renewable Identification Number (RIN) credit under the US Renewable Fuel Standard (RFS) program be used by ocean-going vessels fueling with biodiesel in US ports. The legislation could level US' price playing field. Two bipartisan bills were put forward in support of renewable fuel for ocean-going vessels, one in the US Senate this year and one in the US House of Representatives last year, but they are currently dead in the water. Conventional marine fuels are priced cheaper than biodiesel and green varieties of LNG, ammonia, methanol, and hydrogen. But tightening International Maritime Organization (IMO) and EU regulations are forcing the hand of ship operators to consider green fuels to avoid hefty penalties and having their vessels suspended from trading. Ship owners whose vessels are outfitted with LNG-burning engines, are poised to have the lowest marine fuel expense heading into 2025, as fossil LNG is currently ship owners' cheapest low-carbon fuel option. But retrofitting a vessel to burn LNG could range from $5-$35mn, depending on the size of the vessel. Biodiesel, a plug-and-play fuel that does not require a vessel retrofit, is the second cheapest low-carbon fuel option after fossil LNG. IMO's CII regulation came into force in January 2023 and requires vessels over 5,000 gt to report their carbon intensity, which is then scored from A to E. The scoring levels are lowered yearly by about 2pc, so even a vessel with no change in CII could drop from C to D in one year. If a vessel receives a D score three years in a row or E score in the previous year, the vessel owner must submit a corrective actions plan. E scoring vessels could be prohibited from entering some ports' territorial waters, but this penalty is yet to be imposed on any E vessels. In 2023, the IMO reported that 40pc of the vessels scored A or B, 27pc scored C, 19pc scored D or E and 14pc were unresponsive. The EU's FuelEU maritime regulation will require ship operators traveling in, out and within EU territorial waters to gradually reduce their greenhouse gas (GHG) intensity on a lifecycle basis, starting with a 2pc reduction in 2025, 6pc in 2030 and so on until getting to an 80pc drop, compared with 2020 base year levels. It imposes a penalty of €2,400/t ($2,629/t) of VLSFO equivalent energy for vessel fleets exceeding its GHG limits. By Stefka Wechsler Biodiesel blends* Houston less global ports $/t Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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US tops expectations with 254,000 jobs in Sep


04/10/24
News
04/10/24

US tops expectations with 254,000 jobs in Sep

Houston, 4 October (Argus) — The US added more jobs than expected in September and the unemployment rate ticked down, signs the labor market is strengthening heading into the US presidential election. US nonfarm payrolls rose by 254,000 workers last month, and the jobless rate fell to 4.1pc, the Labor Department reported Friday. Gains in August were revised up by 17,000 to 159,000 and those in July were revised up by 55,000 to 144,000. September's job gains were much higher than the 140,000 estimated by economists in a Trading Economics survey. Job gains blew past expectations in the same month the Federal Reserve began cutting interest rates for the first time since 2020, citing concerns that a weakening labor market might pull down the overall economy. Odds of a quarter point rate cut at the next Fed meeting in November rose to 91pc today from about 68pc Thursday, according to fed funds futures markets, while odds of a half-point cut fell to 9pc. The Fed last month penciled in 50 basis points of cuts in the remainder of this year. Job gains were higher than the average monthly gains of 203,000 over the prior 12 months, the Labor Department reported. Employment continued to move higher in food services and drinking establishments, health care, government, social assistance and construction. The labor market was little affected by Hurricane Francine, which made landfall in Louisiana on 11 September, during the reference periods for the surveys that contribute to the report. Gains in restaurants and drinking places rose by 69,000 jobs, much higher than the average 14,000 added over the prior 12 months. Health care added 45,000 jobs, below the monthly average of 57,000. Government added 31,000 compared with monthly averages of 45,000. Social assistance added 27,000. Construction added 25,000, near the monthly average. Manufacturing lost 7,000 jobs, most of them in the auto industry. The unemployment rate fell from 4.2pc in August, still higher than the five-decade low of 3.4pc posted in early 2023. Average hourly earnings rose by 4pc in the 12 months through September, up from 3.8pc through August. By Bob Willis Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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Thailand's gas production key to future LNG imports


02/10/24
News
02/10/24

Thailand's gas production key to future LNG imports

Singapore, 2 October (Argus) — Thailand's state-controlled upstream firm PTTEP has bet on increasing gas production at the country's largest and oldest Erawan field as the key to reduce Thailand's reliance on LNG imports. This comes as international prices of the super-chilled fuel continue to be rocked by volatility. But casting the spotlight on Erawan could result in the company neglecting to focus on the declining production at other gas fields in Thailand, as well as on similarly vulnerable pipeline gas supplies from Myanmar. Aside from Erawan, Thailand has a group of smaller gas fields, with Bongkot, Bongkot Tai, Pailin and Arthit among the ones with larger production volumes. The eight other gas fields, namely Tan Tawan, Phu Horm, Sirikit, Lanta, Nam Phong, Jasmin, Yoong Thong and the Malaysia-Thailand Joint Development Area, produce much smaller volumes. It is noteworthy that gas production from the smaller gas fields has been on a steady decline since January 2023, and has consistently been below 1mn t every month. Production at Erawan has also been declining over most of 2022-23, but has since ramped up to hit PTTEP's target to achieve 800mn ft³/d (8.2bn m³/yr) of gas production at Erawan by April. Gas production at the Bongkot gas field has similarly showed a promising jump, from well below 400,000 t/month in March 2023 to at least 500,000 t/month since October 2023. But overall domestic gas production in Thailand has held mostly steady, in part because of efforts to ramp up production at Erawan. This has effectively offset lower production at smaller gas fields since 2023. Domestic gas production between January-July averaged around 2.14mn t/month, higher from the monthly average of 1.995mn t in 2023 and the monthly average of 2.072mn t in 2022. Myanmar's largest gas field, the offshore Yadana project, supplies around half of Myanmar's commercial capital Yangon's power needs. The field produces around 6bn m³/yr of gas, of which 70pc is exported to Thailand, where it is sold to state-controlled PTT, and 30pc goes to state-owned Myanmar Oil and Gas (Moge) for domestic use. But Moge has fallen under military control since a February 2021 military coup. This resulted in the US adding another layer of economic restrictions against Moge, which prohibits US-affiliated companies from providing financial services to the company. This could make it increasingly difficult for Thailand to purchase pipeline gas from Myanmar in the future as pipeline gas from the country may eventually reduce or even cease. But given that Myanmar pipeline supplies are marginal to begin with, a complete cessation of pipeline gas imports should be easily resolved through importing additional LNG to make up for the shortfall, traders in Thailand said. LNG imports into Thailand totalled 8.13mn t in 2022, before significantly increasing to 11.32mn t in 2023, according to customs data. Imports into the country so far over January-August stand at 8.2mn t, well on track to potentially surpass 2023 import volumes. By Rou Urn Lee and Naomi Ong Thailand's domestic gas production % Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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