Increase in Offshore Project Costs at Equinor, Aker BP and Vår Energi

Norwegian energy companies Equinor, Aker BP and Vår Energi see their offshore oil and gas projects undergo significant cost increases, mainly due to inflation, delays and currency fluctuations.

Share:

Gain full professional access to energynews.pro from 4.90$/month.
Designed for decision-makers, with no long-term commitment.

Over 30,000 articles published since 2021.
150 new market analyses every week to decode global energy trends.

Monthly Digital PRO PASS

Immediate Access
4.90$/month*

No commitment – cancel anytime, activation in 2 minutes.

*Special launch offer: 1st month at the indicated price, then 14.90 $/month, no long-term commitment.

Annual Digital PRO Pass

Full Annual Access
99$/year*

To access all of energynews.pro without any limits

*Introductory annual price for year one, automatically renewed at 149.00 $/year from the second year.

Norwegian energy companies Equinor, Aker BP and Vår Energi are facing notable increases in the costs of their offshore oil and gas projects. These budget revisions are primarily attributed to imported inflation, delays in project schedules, and exchange rate fluctuations. The recent Norwegian government budget highlighted these financial challenges, revealing that the three companies have upwardly adjusted their cost forecasts for several key projects.

State of Projects and Cost Details

Equinor, a leader in the Norwegian energy sector, revealed that its Johan Castberg project in the Barents Sea, initially estimated at 49 billion kroner in 2018, has seen its costs increase by 76% to now reach 86 billion kroner (approximately 8.08 billion USD). This rise is due to delays and complications encountered in Norwegian shipyards, as well as exchange rate effects. In 2024, costs increased by an additional 2.2 billion kroner compared to the previous year. Project management issues, notably the increased complexity of the construction phase, the impact of infection control measures, and the reduced availability of labor during the pandemic, contributed to this budget drift.

Aker BP, on the other hand, saw its costs for the Yggdrasil project, the largest Norwegian oil and gas development since the start of Johan Sverdrup in 2019, rise from 120.2 billion kroner to 134.4 billion kroner. This increase is mainly due to a depreciation of the Norwegian krone, leading to inflation in the costs of imported equipment. Despite these financial challenges, the project remains on track for production by 2027.

Vår Energi, for its part, faces the highest budget drift with its Balder Future project. Initially approved at 19.6 billion kroner in 2019, the project cost is now estimated at 52.2 billion kroner, more than double its initial estimate. This project has also suffered significant delays, with a start date pushed back to the second quarter of 2025.

Analysis of Cost Overruns

The main reasons for the cost overruns include supply chain issues and increased project complexity. Additional labor costs and the complexity of installation particularly impacted the Johan Castberg project. The COVID-19 pandemic also slowed work in the shipyards in Singapore, where several key modules originate. Furthermore, a weakened Norwegian krone has generated imported inflation on equipment and services, especially for large-scale projects requiring specific parts from abroad.

Aker BP is also facing legal challenges related to the approval of the Yggdrasil project by the Ministry of Energy, due to opposition from environmental groups concerned about the project’s environmental impact. These combined factors have contributed to increased costs and delays in project execution.

Strategic and Economic Consequences

The cost increases of projects could have significant impacts on the companies’ profit margins, especially in a context of volatile energy prices. Production delays also affect the long-term profitability of projects. However, Equinor emphasized that the Johan Castberg project remains profitable with a break-even point around 35 USD per barrel, well below current market levels.

These budgetary increases can also influence companies’ future investment decisions and affect their competitiveness in the international market. Delays in project schedules can lead to a loss of confidence from investors and business partners, potentially complicating the financing of future projects.

Perspectives and Challenges

Despite these challenges, Equinor, Aker BP and Vår Energi continue their investments, betting on additional discoveries and a gradual ramp-up of existing infrastructures. However, pressure from environmental groups and uncertainties related to rising costs increase the risks, particularly for projects like Yggdrasil that may be delayed if legal appeals are successful. These developments reflect the growing difficulty of conducting offshore extraction projects in increasingly hostile regions, where infrastructure costs and delays can quickly erode expected profitability.

Finnish President Alexander Stubb denounced fossil fuel imports from Russia by Hungary and Slovakia as the EU prepares its 19th sanctions package against Moscow.
Japanese giant JERA has signed a letter of intent to purchase one million tonnes of LNG per year from Alaska, as part of a strategic energy agreement with the United States.
US-based Chevron has submitted a bid with HelleniQ Energy to explore four offshore blocks south of Crete, marking a new strategic step in gas exploration in the Eastern Mediterranean.
GTT has been selected by Samsung Heavy Industries to design cryogenic tanks for a floating natural gas liquefaction unit, scheduled for deployment at an offshore site in Africa.
A consortium led by BlackRock is in talks to raise up to $10.3 billion to finance a gas infrastructure deal with Aramco, including a dual-tranche loan structure and potential sukuk issuance.
TotalEnergies commits to Train 4 of the Rio Grande LNG project in Texas, consolidating its position in liquefied natural gas with a 10% direct stake and a 1.5 Mtpa offtake agreement.
US producer EQT has secured a twenty-year liquefied natural gas supply contract with Commonwealth LNG, tied to a Gulf Coast terminal under development.
The Chief Executive Officer of TotalEnergies said that NextDecade would formalise on Tuesday a final investment decision for a new liquefaction unit under the Rio Grande LNG project in the United States.
Monkey Island LNG has awarded McDermott the design of a gas terminal with a potential capacity of 26 MTPA, using a modular format to increase on-site output density and reduce execution risks.
The Voskhod and Zarya vessels, targeted by Western sanctions, departed China’s Beihai terminal after potentially offloading liquefied natural gas from the Arctic LNG 2 project.
ADNOC Gas will join the FTSE Emerging Index on September 22, potentially unlocking up to $250mn in liquidity, according to market projections.
Norwegian company BlueNord has revised downward its production forecasts for the Tyra gas field for the third quarter, following unplanned outages and more impactful maintenance than anticipated.
Monkey Island LNG adopts ConocoPhillips' Optimized Cascade® process for its 26 MTPA terminal in Louisiana, establishing a technology partnership focused on operational efficiency and competitive gas export pricing.
NextDecade has signed a liquefied natural gas supply agreement with EQT for 1.5 million tonnes annually from Rio Grande LNG Train 5, pending a final investment decision.
Sawgrass LNG & Power has renewed its liquefied natural gas supply agreement with state-owned BNECL, consolidating a commercial cooperation that began in 2016.
Gazprom and China National Petroleum Corporation have signed a binding memorandum to build the Power of Siberia 2 pipeline, set to deliver 50 bcm of Russian gas per year to China via Mongolia.
Permex Petroleum signed a $3 million purchase option on oil and gas assets in Texas to support a strategy combining energy production and Bitcoin mining.
Enbridge announces the implementation of two major natural gas transmission projects aimed at strengthening regional supply and supporting the LNG market.
Commonwealth LNG’s Louisiana liquefied natural gas project clears a decisive regulatory step with final approval from the U.S. Department of Energy for exports to non-free trade agreement countries.
The Indonesian government confirmed the delivery of nine to ten liquefied natural gas cargoes for domestic demand in September, without affecting long-term export commitments.

Log in to read this article

You'll also have access to a selection of our best content.