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Oil and gas to play a role for a 'long time': Shell

  • Spanish Market: Crude oil, Electricity, Natural gas
  • 18/03/24

Oil and gas will play a role in the global energy needs for a "long, long, long time to come," said Shell chief executive Wael Sawan today.

Sawan is working to move beyond a dialogue that "seems to fixate" on the notion one must choose between fossil fuels like oil and gas or renewables like solar and wind.

"It's all. And we need them in abundance," Sawan told participants at CERAWeek by S&P Global conference in Houston today.

Stable oil production is deemed necessary by Shell as it transitions its customers to lower carbon solutions over the course of decades. Energy security in the EU is also top of mind for Sawan, who acknowledges the tough choices government heads must make when choosing where to spend their marginal dollar. But he still sees strategies that do not adequately address long term supply needs.

"I still think we rely too much on chance in that regard," said Sawan, but noted it is "definitely much more pragmatic and much more realistic than maybe a few years ago."

"The positive thing that we've tried to reinforce for Europe is that energy transition and energy security for you and Europe are one in the same, because you don't have too many options," Sawan said, highlighting coal decommissioning, nuclear project lead times and declining oil and gas production.

"Unfortunately, there's still more politicization of energy than there needs to be."

Freight disruption in the Red Sea is having "very little" effect on LNG movements, according to Sawan, largely because of supply and demand being "nicely balanced" on either side of the Suez Canal. Sellers on the east side can swap with counterparties on the west side to minimize disruption to trade flows.


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07/11/25

Australia's Hydro Tasmania prepares for GOO issuances

Australia's Hydro Tasmania prepares for GOO issuances

Sydney, 7 November (Argus) — Australian utility Hydro Tasmania expects to generate the first guarantees of origin (GOOs) under the newly launched renewable electricity certification "in early 2026", the company has told Argus , after the scheme officially started earlier this week. The Tasmanian state government-owned utility is making preparations "consistent with the GOO scheme requirements", it said, adding that it aims to provide its customers with the products that they want, including large-scale certificates (LGC), international renewable energy certificates (I-RECs) or GOOs. Most of Hydro Tasmania's hydropower stations were commissioned before 1997 and, as such, they have largely been excluded from LGC creation under the current Renewable Energy Target (RET) framework. The scheme sets an individual baseline based on average output, with plants able to create LGCs only for generation above that. Around 80pc of the utility's average annual generation is "below baseline", making up about 8TWh, which is more than half of the total below-baseline generation in Australia. Generation from these assets has been issued in recent years with I-RECs, a parallel voluntary framework that mostly applies to electricity consumption outside Australia, when businesses have operations overseas. Under the newly launched GOO scheme , renewable guarantees of origin (Regos) can be issued for below-baseline generators but are subject to restrictions on their validity and use. In particular, they must be retired within 18 months from electricity generation or dispatch, whereas standard certificates can be retired for up to 36 months. They can only be used as input to a product guarantee of origin (PGO) — another type of certificate in the new framework — or be retired for a facility carrying out "emissions-intensive trade-exposed" activities. Alternatively, they can also be retired for the purposes of self-consumption. "Legacy baselines" for facilities operational before 1997 "will apply until the end of 2030", a spokesperson at Australia's Department of Climate Change, Energy, the Environment and Water (DCCEEW) told Argus , adding that once that baseline is met each year, "any Rego certificates created […] in the same year won't be labelled as below-baseline". With Regos and LGCs now coexisting until 2030, "facilities can participate in both schemes at the same time", Australia's Clean Energy Regulator (CER) said earlier this week, "but cannot claim LGCs and Rego certificates for the same electricity". The same applies to Regos and I-RECs. Argus understands this leaves pre-1997 stations with the ability to create both LGCs for above-baseline and REGOs or I-RECs for below-baseline in the same year, which was one of points raised by Hydro Tasmania in response to a consultation on draft GOO rules earlier this year. While agreeing with the 18-month retirement limitation, the utility had also requested that it be applied to all Regos, to have better alignment between consumer claims and actual power consumption. Some market participants had raised concerns last year about allowing below-baseline generation to issue Regos, as these facilities have already been paid for through taxes and energy charges and because it could create uncertainty for new renewable energy investments. By Giulio Bajona Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Prices rise in French biomethane RGGO auction


06/11/25
06/11/25

Prices rise in French biomethane RGGO auction

London, 6 November (Argus) — The European Energy Exchange (EEX) nearly sold out of available French biomethane renewable gas guarantees of origin (RGGOs) at its November auction, with average prices reflecting those in the over-the-counter (OTC) market since the August auction. As the final auction of 2025, this completes the average 2025 auction price for French RGGO taxes. All but 1MWh of the offered 144GWh of RGGOs were sold in the 5 November auction for a weighted average price of €13.98/MWh. EEX calculated the reference price for the auction at €13.96/MWh. Prices averaged €12.18/MWh in the previous auction, when 107GWh of RGGOs traded in August. Initially, 147GWh produced in March-June was eligible to go into the auction . Three French municipalities pre-empted 2.98GWh of the volumes before the auction, up from 2.16GWh from one municipality before the August auction. Argus assessed French uncertified RGGOs for 2025 production at €13.90/MWh on 30 October. Bids for French uncertified RGGOs had been around €12.50/MWh at the time of the previous auction. Certified, ETS-eligible RGGOs did not sell at a premium to uncertified or non-ETS eligible volumes. As in previous auctions, EEX cannot transfer ownership of the Proof of Sustainability for any volumes sold, which limits their use for compliance. For volumes sold in the OTC market, Argus assessed certified, ETS-eligible French RGGOs from any feedstock at a €9.10/MWh premium to uncertified equivalent. The French government now applies a floor for declared tax levels for 75pc of the sale of RGGOs that are not used in transport. This is based on 75pc of the average reference prices from auctions the previous year to the production. The average of the EEX reference prices for the four 2025 auctions is €10.86/MWh, which would mean a floor of €8.14/MWh. Argus assessed 2026 vintage uncertified RGGOs at €16/MWh on 30 October. Only RGGOs from subsidy-supported biomethane, where the subsidy contract was signed after 9 November 2020, are auctioned on the EEX. Around 405GWh of biomethane RGGOs were auctioned in 2025. By Emma Tribe Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

MEG shareholders approve Cenovus deal


06/11/25
06/11/25

MEG shareholders approve Cenovus deal

Calgary, 6 November (Argus) — MEG Energy shareholders today approved selling the Canadian oil sands producer to larger rival Cenovus Energy, clearing the way for the merger to close by year-end. The vote in favor of the cash-and-stock deal that values MEG at about C$8.6bn ($6.2bn) brings an end to a lengthy pursuit of the oil sands company by Cenovus and Strathcona Resources. All three companies are based in Calgary, Alberta. The deal was approved by "more than 86pc of the votes," MEG board chair James McFarland said during Thursday's shareholders meeting. Two-thirds support was required for the transaction to go through. Cenovus is among the largest oil sands producers and will grow to 750,000 b/d of output in the region after acquiring MEG's 110,000 b/d Christina Lake asset. Cenovus' neighbouring Christina Lake project to the southwest is one of the biggest oil sands projects in the industry at about almost 250,000 b/d. Cenovus's overall third quarter production came in at 833,000 b/d of oil equivalent (boe/d), including production outside of the oil sands region. Cenovus executives plan to increase output at MEG's Christina Lake asset to 150,000 b/d by the end of 2028 , more than the 135,000 b/d targeted by MEG's management. Cenovus would do this by utilizing unused oil treating capacity along with adding a sixth steam generator that it has in inventory. Cenovus said it expects C$150mn in annual cost savings from the deal in the near-term, rising to C$400mn/yr in 2028 and beyond. MEG's second-largest shareholder, Strathcona Resources, put the company in play with a hostile takeover bid earlier this year before Cenovus swooped in to strike a deal. Strathcona with its 14.2pc share of MEG vowed to vote against the Cenovus-MEG deal and those votes were key with Cenovus admitting on 21 October it had come up short of the two-thirds support required. Since then, Strathcona dropped its bid and made a side deal with Cenovus to throw its support behind the proposed transaction. By Brett Holmes Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

UAE's Adnoc holds line on 5mn b/d crude capacity push


06/11/25
06/11/25

UAE's Adnoc holds line on 5mn b/d crude capacity push

Dubai, 6 November (Argus) — Abu Dhabi's state-owned Adnoc is pressing ahead with plans to lift crude production capacity to 5mn b/d by 2027, undeterred by this year's lower oil prices and the significant capital required to sustain output from ageing fields. Adnoc reported in May 2024 that its maximum sustainable capacity had reached 4.85mn b/d, up from 4.65mn b/d previously. Upstream chief executive Musabbeh al-Kaabi gave the same figure this week on the sidelines of the Adipec conference in Abu Dhabi. Adnoc's long-term investment programme remains intact, and onshore and offshore drilling activity is "extremely busy" as the company ramps up brownfield expansions to complete the final stretch of its capacity-build plan, al-Kaabi said. "Raising capacity to 5mn b/d will require massive investment to sustain," he added, noting that some of Abu Dhabi's legacy fields will need continual infill drilling and redevelopment to offset natural decline. Al-Kaabi framed the strategy as both a commercial and policy priority, echoing projections made by Adnoc chief executive Sultan al-Jaber in his Adipec opening speech that global oil demand will remain above 100mn b/d through 2040 and beyond. "Because Abu Dhabi crude is among the lowest-carbon barrels globally, it's our responsibility to ensure secure and affordable supply," al-Kaabi said. He also underscored the importance of maintaining spare capacity as a strategic buffer, despite the financial cost of holding back supply. "It's in our interest to ensure the market is stable whenever there is demand for low-carbon crude. Stability and predictability are great for investment," he said. In a high oil price environment, "it takes only two or three years of maximum production to recover all costs", he added. The maximum sustainable capacity of the 22-member Opec+ alliance is under renewed scrutiny, with the group due to begin updating each member's production baseline to calculate targets for 2027. Opec+ agreed in September on a mechanism to assess members' maximum sustainable capacity, but the process is expected to be contentious, as countries often claim inflated figures to secure higher output quotas. The UAE has already secured two upward quota revisions in 2022 and 2023 to reflect its growing capacity. Given the pace of capacity gains in the last few years and how close Adnoc is to its target, the company may announce it has reached 5mn b/d capacity ahead of schedule. By Bachar Halabi and Nader Itayim Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

No FID for Lake Charles LNG until equity selldown


05/11/25
05/11/25

No FID for Lake Charles LNG until equity selldown

Houston, 5 November (Argus) — Energy Transfer will not commit to a final investment decision (FID) on its proposed 16.5mn t/yr (2.2bn ft³/d) Lake Charles LNG export facility in Louisiana until it has sold off 80pc of equity stakes in the project, co-chief executive Mackie McCrea told investors today. The project currently is fully owned by Energy Transfer, casting doubt on the company's plan to reach FID by the end of the year. Investor MidOcean Energy signed a preliminary agreement in April to fund 30pc of the project's construction costs in exchange for 30pc of offtake, or about 5mn t/yr, but the two sides have yet to finalize the deal. Nearly all of the project's offtake is contracted, with 11.9mn t/yr set aside to binding agreements. But the "last, big, most important box" is adding equity partners, McCrea said. McCrea said "we've got our work cut out for us" to sell down equity stakes before needing to reset the terms of its engineering, construction and procurement contract with contractors Technip Energies and KBR. "Let me make this real clear: We will not proceed with LNG until we have secured 80pc of equity partners similar to ourselves," McCrea said. The midstream firm has sought for years to convert the existing Lake Charles import facility into an export terminal. Shell signed on with a 50pc stake in 2019 but pulled out the following year as part of cost-cutting measures during the Covid-19 pandemic. Energy Transfer also has extensive assets in crude oil and NGL infrastructure. "When you're chasing billions of dollars in projects, several of which we've already announced, we've got to be careful stepping out on something like this," McCrea said. "We're not an LNG company like we compete with. We're a pipeline company that has a regas facility converting part of it to LNG." Lake Charles LNG, located in southwest Louisiana, is fully permitted by US federal regulators through 2031 after receiving extensions from the US Department of Energy and the Federal Energy Regulatory Commission earlier this year. By Tray Swanson Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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