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Iraq and KRG reach deal on 2021 budget

  • Spanish Market: Crude oil
  • 20/12/20

Baghdad has reached a deal with the Kurdistan Regional Government (KRG) in northern Iraq over the 2021 economic budget, which could pave the way for its approval within a week, according to finance minister Ali Allawi.

"The ministry reached an agreement with [the Kurdistan region] on the 2021 budget, and the present delegation is discussing its allocations for the year 2020," Allawi was quoted as saying by state-owned news agency Ina.

The draft budget — which requires parliamentary approval — assumes an oil price of $42/bl next year and crude exports of 3.25mn b/d. It could now reach parliament for a vote "within a week", Allawi said.

The 2021 draft budget is based on oil revenues of 73 trillion Iraqi dinar ($60.9bn), representing only 80pc of total government revenues. This is down from as high as 90pc in some previous budgets.

But Allawi did not address the issue of KRG oil exports — an issue which has caused delays to the progression of the draft budget. He only said "the Kurdistan region exports its oil at prices that are less than [state-owned marketer] Somo oil by $5/bl to $7/bl."

The draft budget states that the KRG must hand over 250,000 b/d of crude to Somo in order to receive its share of the federal budget, a clause that has long been a point of contention between Baghdad and Erbil.

The KRG has said it is unable to hand this over to Somo because of its long-term contracts with trading companies that previously provided loans, an Iraqi official told Argus last week, adding that politicians would need to find financial solutions in order to move forward.

Under the draft budget, Baghdad has agreed to pay transport costs for this 250,000 b/d of crude through the KRG export pipeline to the Turkish port of Ceyhan, in addition to 100,000 b/d of Kirkuk crude that the federal government currently exports through the pipeline. KRG crude exports have averaged around 415,000 b/d so far this year, which means it would have to pay the transport costs for the remaining 165,000 b/d itself.

Another sticking point has been plans by the government to devalue the Iraqi dinar in an attempt to help it navigate the liquidity crisis that was brought on by the collapse in oil prices earlier this year. A decision to move ahead with the plan was taken by the central bank yesterday, announcing that it had set the new rate at ID1,450 per dollar.

"The central bank will add a margin to the specified price," Allawi said. "The margin that the central bank will add will not be large and may reach ID1,490."

This is down from the earlier exchange rate of ID1,182 that had been in place since December 2015. A weaker dinar should help the government's balance sheet. The high cost of salaries has been difficult for Baghdad to cover in a low oil price environment.


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07/11/25

Petrobras increases spending by 24pc in 3Q: Update

Petrobras increases spending by 24pc in 3Q: Update

Updates with investment plans in paras 3-4 and explorations plans in paras 8-9 Rio de Janeiro, 7 November (Argus) — Brazilian state-controlled Petrobras' investments increased by 24pc in the third quarter from a year earlier, as the firm continues to focus on production in the offshore pre-salt. Petrobras spent $5.5bn in capital expenditure (capex) in July-September, of which $4.7bn was for exploration and production. Of this investment in exploration and production, $2.7bn went to developing production of the pre-salt cluster in the Santos basin, particularly the construction of seven new floating production, storage and offloading units that will serve the Buzios, Atapu and Sepia fields. A further $900mn went to developing production in the Campos basin's pre- and post-salt, and $500mn went to exploration. Total investments over the first nine months of the year were $14bn, a 29pc increase on the same period last year. The company has speeded up investment execution due to projects being brought forward, rather than higher costs, and is on track to meet guidance by year's end, directors said. Capex guidance for 2025 as outlined in Petrobras' 2025-2029 business plan is $18.5bn. The firm is due to present an updated plan at the end of November. There are no plans to cut investments next year, said the director for engineering, technology and innovation, Renata Baruzzi. Petrobras posted a profit of R32.7bn ($6bn) in the third quarter, a 0.5pc increase on the same quarter last year and 23pc more than in the previous quarter. Higher crude production as well as stronger crude exports and domestic sales of diesel drove the third quarter result, Petrobras said. It also cited a small rallying of oil prices, with the price of Brent growing by 2pc compared with the second quarter, and lower operational costs, as contributing factors. The company's board approved a payout of R12.16bn ($2.3bn) to shareholders, or R0.9432/share, down from R1.3282/share a year earlier. Dividends will be paid in two installments, in February and March. Exploration going forward Petrobras celebrated receiving regulatory approval last month to drill an exploratory well in the Foz do Amazonas basin off Brazil's northern coast. This is the most coveted area in the equatorial margin, a new oil frontier which could contain reserves similar to those found off Guyana. The company hopes to find oil in this first well, named Morpho, but if not it will continue exploration, director for exploration and production Sylvia Anjos said. "We are already planning for eight wells in the region," she said. By Constance Malleret Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Opec+ eight apply brakes to output rises


07/11/25
07/11/25

Opec+ eight apply brakes to output rises

London, 7 November (Argus) — Eight core Opec+ members have put the brakes on their monthly production increases, giving them time to assess the impact of new US sanctions on Russia. Saudi Arabia, Iraq, Kuwait, Russia, the UAE, Algeria, Oman and Kazakhstan will make one last production target increase worth 137,000 b/d in December before pausing the hikes in January-March. The pause ends nine consecutive months of production target increases, during which the eight have fully unwound a 2.2mn b/d set of cuts and in October started to unwind another set of cuts worth 1.65mn b/d. The group has agreed to three monthly increases worth a combined 411,000 b/d up to December, leaving 1.24mn b/d to unwind. The eight officially attributed the pause to "seasonality", referring to expectations of lower oil demand in the first quarter of 2026. But more importantly, the pause will allow them to gauge the impact of recent US sanctions on Russian oil producers Rosneft and Lukoil. Whether Russia can maintain its crude output and exports under the new restrictions remains uncertain. If Rosneft and Lukoil cannot find workarounds to the sanctions and buyers for their crude, they may have to start reducing production. In such an event, Opec+ may feel the need to step in to replace lost Russian output. "I think everyone is monitoring the Russia sanctions and it's difficult for them to actually predict how those sanctions will go," trading firm Mercuria's chief executive Marco Dunand says. "I think they are pausing because there is a lot of oil on the water... I think it's about 60mn bl, but I'm not sure." The eight countries said their decision reflects a "cautious approach", but they reiterated their "full flexibility" to accelerate, pause or reverse the monthly output hikes, depending on market conditions. "The group wants to adopt a more cautious approach, exactly like it did at the beginning of 2025, when it decided to delay the unwinding process of the initial 2.2mn b/d voluntary cut until April," one delegate told Argus. No consensus But views on the oil market remain sharply divided. The IEA forecasts a significant supply surplus in the fourth quarter and in 2026, while Opec expects a more balanced market, underpinned by strong demand this year and next. Speaking at the Adipec conference in Abu Dhabi, UAE energy minister Suhail al-Mazrouei said he "can't see or justify" an oversupply scenario. "All of what we are seeing is more demand," he said. European oil majors are also divided on market fundamentals. While Shell chief executive Wael Sawan sees a "highly credible scenario" for oversupply in 2026, BP and TotalEnergies have pushed back against a near-term oil glut , arguing that demand remains resilient and non-Opec+ supply growth is likely to taper off next year. "The determination of what happens really sits around three factors — Opec+ choices, China's stockpiling behaviour and the sanctions environment," BP chief executive Murray Auchincloss says. Oil prices rebounded from multi-month lows of around $60/bl after the US unveiled its sanctions on 22 October, with Ice front-month Brent now around $65/bl. But this is still below where many Opec+ members would prefer. Production by the eight members had increased by 2.1mn b/d in October from when they started unwinding their cuts in April, according to Argus estimates. Production by the 18 members of the alliance that adhere to output targets rose by 30,000 b/d on the month to 36.2mn b/d in October — the group's highest production since April 2023 (see table). By Aydin Calik, Nader Itayim and Bachar Halabi Opec+ crude production mn b/d Oct Sep* Oct target† ± target Opec 9 23.05 22.95 23.19 -0.14 Non-Opec 9 13.15 13.22 13.27 -0.12 Total Opec+ 18 36.20 36.17 36.46 -0.26 *revised †includes extra cuts agreed in Apr 23 and Nov 23 Opec wellhead production mn b/d Oct Sep* Oct target† ± target Saudi Arabia 10.01 9.98 10.02 -0.01 Iraq 4.11 4.08 4.24 -0.13 Kuwait 2.57 2.52 2.56 +0.01 UAE 3.36 3.38 3.39 -0.03 Algeria 0.97 0.97 0.96 0.01 Nigeria 1.52 1.51 1.50 +0.02 Congo (Brazzaville) 0.26 0.25 0.28 -0.02 Gabon 0.21 0.21 0.18 +0.03 Equatorial Guinea 0.04 0.05 0.07 -0.03 Opec 9 23.05 22.95 23.19 -0.14 Iran 3.39 3.45 na na Libya 1.32 1.37 na na Venezuela 1.00 1.05 na na Total Opec 12^ 28.76 28.82 na na *revised †includes extra cuts agreed in Apr 23 and Nov 23 ^Iran, Libya and Venezuela are exempt from production targets Non-Opec crude production mn b/d Oct Sep* Oct target† ± target Russia 9.41 9.37 9.49 -0.08 Oman 0.80 0.79 0.80 -0.00 Azerbaijan 0.45 0.44 0.55 -0.10 Kazakhstan 1.68 1.83 1.56 +0.12 Malaysia 0.36 0.36 0.40 -0.04 Bahrain 0.18 0.18 0.20 -0.02 Brunei 0.10 0.08 0.08 0.02 Sudan 0.01 0.02 0.06 -0.05 South Sudan 0.16 0.15 0.12 +0.04 Total non-Opec 13.15 13.22 13.27 -0.12 *revised †includes extra cuts agreed in Apr 23 and Nov 23 Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Petrobras increases spending by 24pc in 3Q


07/11/25
07/11/25

Petrobras increases spending by 24pc in 3Q

Rio de Janeiro, 7 November (Argus) — Brazilian state-controlled Petrobras' investments increased by 24pc in the third quarter from a year earlier, as the firm continues to focus on production in the offshore pre-salt. Petrobras spent $5.5bn in capital expenditure (capex) in July-September, of which $4.7bn was for exploration and production. Of this investment in exploration and production, $2.7bn went to developing production of the pre-salt cluster in the Santos basin, particularly the construction of seven new floating production, storage and offloading units that will serve the Buzios, Atapu and Sepia fields. A further $900mn went to developing production in the Campos basin's pre- and post-salt, and $500mn went to exploration. Total investments over the first nine months of the year were $14bn, a 29pc increase on the same period last year. Capex guidance for 2025 as outlined in Petrobras' 2025-2029 business plan is $18.5bn. Petrobras posted a profit of R32.7bn ($6bn) in the third quarter, a 0.5pc increase on the same quarter last year and 23pc more than in the previous quarter. Higher crude production as well as stronger crude exports and domestic sales of diesel drove the third quarter result, Petrobras said. It also cited a small rallying of oil prices, with the price of Brent growing by 2pc compared with the second quarter, and lower operational costs, as contributing factors. The company's board approved a payout of R12.16bn ($2.3bn) to shareholders, or R0.9432/share, down from R1.3282/share a year earlier. Dividends will be paid in two installments, in February and March. By Constance Malleret 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.

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