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New Equinor Gas Discovery in Norway Eyed to Supply Poland

by Jov Onsat|Rigzone Staff | Friday, January 23, 2026 |

Equinor ASA and ORLEN SA have announced a natural gas discovery on Norway's side of the North Sea, with plans to connect it to the Baltic Pipe to supply Poland.

The Sissel discovery in production license (PL) 1137 is estimated to hold 6.3-28.3 million oil-equivalent barrels, mainly gas with condensate admixture, Poland's majority state-owned ORLEN said in a statement on its website. Sissel, or well 15/8-3 S, is the first exploration well drilled in PL1137, awarded 2022, according to a separate press release by the Norwegian Offshore Directorate.

"The Sissel discovery, from which we expect to obtain approximately one billion cubic meters [35.31 billion cubic feet] of gas, strengthens our asset portfolio in Norway and represents another step toward achieving the ORLEN Group’s strategic objectives", said ORLEN president Ireneusz Fafara. "Norwegian gas plays a crucial role in ensuring stable supplies for our customers. This was clearly demonstrated earlier this year, when we recorded record‑high demand from the energy sector, businesses and households - reaching as much as 100 million cubic meters in a single day.

"In response, we increased gas imports, including via the Baltic Pipe, which transports gas from the Norwegian continental shelf to Poland.

“As a company fundamental to Poland’s energy security, we remain firmly committed to further developing cooperation with our Norwegian partners based on our own production on the Shelf".

The partners are considering tying back Sissel to the Utgard field, itself a tieback to the Sleipner complex.

PL1137, in the central part of the North Sea, sits 250 kilometers (155.34 miles) from Stavanger city in southwestern Norway, according to ORLEN. Norway's majority state-owned Equinor is operator with a 50 percent stake, the other half held by ORLEN.

The discovery, with a total depth of 4,359 meters (14,301.18 feet), is five kilometers north of Utgard, ORLEN noted. Utgard, operated by Equinor with ORLEN as its main partner, started producing 2019.

"Later this year, ORLEN Upstream Norway plans to launch Eirin, another field in this area, which will be developed using Gina Krog and Sleipner infrastructure", ORLEN added, noting Sleipner accounted for nearly 30 percent of its Norwegian production last year.

ORLEN board member Wieslaw Prugar said, "The Sissel discovery confirms effectiveness of our exploration strategy, which focuses on resources located close to existing installations".

"Sissel can be developed as a tieback to this infrastructure, enabling a rapid startup and significantly reducing investment costs", Prugar added. "This project will also help offset natural production declines at Utgard, extending the life of its infrastructure.

"By leveraging these synergies, we maximize economic and operational efficiency in our upstream operations, while ensuring stable gas supplies for our customers in Poland and Central Europe".
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Equinor Makes Two Large Gas Discoveries in Norway’s North Sea

By Tsvetana Paraskova - Dec 05, 2025

Equinor announced on Friday two gas and condensate discoveries in the Norwegian part of the North Sea in its largest discoveries so far this year that can be developed through existing infrastructure.

Equinor made the discoveries in the Lofn and Langemann wells in the Sleipner area of the North Sea, in a license located between the operating Gudrun and Eirin fields.

Preliminary estimates indicate the reservoirs may contain between 30 and 110 million barrels of recoverable oil equivalents.

“The Sleipner area is an important hub for Norwegian gas exports to Europe. These discoveries strengthen our optimism for further exploration in the area,” said Kjetil Hove, executive vice president for Exploration & Production Norway at Equinor.

Equinor and its partners in the licenses plan to drill five additional exploration wells, Hove added, noting that “adding new volumes is essential to maintain export capacity and value creation from the area.”

Discoveries near existing fields can be developed quickly through subsea facilities, with limited environmental impact, very low CO2 emissions from production, and strong profitability, Hove said.

Equinor and other operators on the Norwegian Continental Shelf are exploring prospects near operational fields to take advantage of the existing infrastructure to raise oil and gas production via tie-backs and tie-ins, which are cheaper than investing in standalone developments.

Earlier this week, Vår Energi confirmed an oil discovery very close to its Goliat field in the Barents Sea, the first operating Arctic oilfield offshore Norway.

Norway has been boosting its gas production since 2022 when it overtook Russia as Europe’s top gas supplier. Not a member of the EU, but a NATO founding member and key EU and UK ally, Norway looks to continue providing the gas Europe needs.

Companies operating offshore Norway are raising production of gas and oil, with the support of the Norwegian government, which continues to bet on the oil and gas industry and the massive revenues it raises for the country and its sovereign wealth fund, the world’s largest.

Le géant norvégien Equinor dans le rouge au 3e trimestre, malgré une hausse de sa production

Connaissance des Énergies avec AFP le 29 octobre 2025

Le géant norvégien de l’énergie Equinor a annoncé mercredi une perte nette de 210 millions de dollars au troisième trimestre, conséquence de dépréciations d’actifs liées à la révision à la baisse de ses prévisions sur les prix du pétrole.

Un baril estimé à 75 $ entre 2030 et 2040

Cette perte, qui contraste fortement avec un bénéfice de 2,29 milliards de dollars enregistré à la même période l’an dernier, s’explique principalement par la dépréciation de 754 millions de dollars d’actifs, notamment dans l’offshore aux États-Unis.

Equinor table désormais sur un prix du baril légèrement inférieur, estimé à 75 dollars entre 2030 et 2040. La dégradation des résultats s’explique également par une baisse de 14 % du prix du pétrole Brent depuis le troisième trimestre 2024, ainsi que par une fiscalité plus lourde, liée notamment à la fin de certains mécanismes d’imposition différée.

Une production en hausse

Indicateur privilégié du groupe, le résultat d’exploitation ajusté - qui neutralise certains éléments exceptionnels - s’établit à 6,2 milliards de dollars, soit un recul de 10 % sur un an. Ce résultat ressort légèrement en deçà des prévisions des analystes interrogés par Equinor, qui anticipaient 6,3 milliards de dollars.

La production d’hydrocarbures a quant à elle progressé de 7 % sur un an, atteignant 2,13 millions de barils équivalent-pétrole par jour, portée par une hausse de 9 % de l’extraction sur les champs norvégiens.

Equinor Starts Up New Field for Hammerfest LNG

by Jov Onsat|Rigzone Staff | Wednesday, September 24, 2025

Equinor ASA and its partners have put onstream the Askeladd West field in the Barents Sea, unlocking new feed gas for Hammerfest LNG.

"Askeladd Vest is an important step in the development of the Snohvit field and will help maintain full production at Hammerfest LNG until onshore compression starts as part of the Snohvit Future project in 2028", Grete B. Haaland, Equinor senior vice president for exploration and production in Northern Norway, said in an online statement Tuesday.

Snohvit, the first hydrocarbon development in the Barents Sea according to Equinor, has been producing since 2007. The Snohvit Future project, approved 2023, involves onshore compression to ensure the flow of gas and electrification to curb emissions. Equinor expects the onshore compression component to be completed 2028. From 2030, Snovhit is expected to shift to electrified operation.

Hammerfest LNG meanwhile started operations 2022. The plant on the island of Melkoya cools gas into liquefied natural gas (LNG) for export overseas. It has a production capacity of 6.5 billion standard cubic meters (Bscm) a year, equivalent to about five percent of the Nordic country's total gas exports and about two percent of the European Union's gas needs, according to Equinor. It is the only facility in Northern Europe liquefying and exporting natural gas, according to Equinor.

Snohvit supplies the liquefaction plant via a 143-kilometer (88.86 miles) pipeline. Feed gas began flowing from the Askeladd field December 2022.

Askeladd West, the newest source field for Hammerfest LNG, consists of two wells and a new well template tied back to Askeladd. Askeladd West is connected to Hammerfest LNG via 195 kilometers of pipeline, according to Equinor.

"The [Askeladd West] field contributes to continued high and long-term production of LNG from the processing plant at Melkoya", Equinor said Tuesday.

Askeladd West holds recoverable volumes of about 15 Bscm. It has an investment of NOK 3 billion ($302.91 million), according to Equinor.

"Askeladd Vest is a highly profitable project", said Trond Bokn, Equinor senior vice president for project development. "The project has received substantial deliveries from the Norwegian supplier industry and has created ripple effects on both the local, regional and national scale".

Norway's majority state-owned Equinor operates Askeladd West with a 36.79 percent stake through Equinor Energy AS. Petoro AS, also owned by the Norwegian government, holds 30 percent. The other partners are France's TotalEnergies SE through TotalEnergies EP Norge AS (18.4 percent), local player Var Energi ASA (12 percent) and Scotland-based Harbour Energy PLC through Harbour Energy Norge AS (2.81 percent).

Norway's Northernmost Oil Field Officially Opens

by Andreas Exarheas|Rigzone Staff | Tuesday, August 12, 2025

The Johan Castberg field was officially opened by Norway’s minister of energy, Terje Aasland, on August 8, the field’s operator, Equinor, announced in a statement posted on its site recently.

The official opening was attended by the crew of the Johan Castberg FPSO, leaders from Norway’s Ministry of Energy, the mayors of Hammerfest and Harstad, leaders from the Norwegian Offshore Directorate (NOD), the Norwegian Ocean Industry Authority, Equinor, Vår Energi, Petoro, Aker Solutions, and employee representatives, Equinor revealed in the statement.

The field will produce for at least 30 years, according to Equinor’s statement, which noted that “this creates great value and ripple effects and is important for Norway’s role as a reliable, long-term energy supplier”.

The field produces 220,000 barrels of oil per day and consists of the Skrugard, Havis and Drivis discoveries, which were discovered from 2011 to 2014, Equinor highlighted in the statement. The field development concept consists of a production vessel tied back to an extensive subsea field with a total of 30 wells divided on 10 subsea templates and two satellite structures, the company noted.

Every three or four days, cargoes depart from Johan Castberg, according to the statement, which said that each cargo may be worth around NOK half a billion ($48.7 million), “depending on the oil price”.

Johan Castberg is located approximately 100 kilometres (62 miles) north of the Snøhvit field in the Barents Sea in blocks 7219/9 and 7220/4,5,7, about 150 km (93 miles) from Goliat and almost 240 km (149 miles) from Melkøya, Equinor pointed out in the statement, highlighting that the water depth in the area is 360-390 meters (1,181-1,279 feet).

“This is a milestone for the petroleum industry in the Barents Sea,” Aasland said in a speech to the FPSO crew right after the opening, the Equinor statement highlighted.
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Equinor déprécie un grand projet éolien au large de New York

Connaissance des Énergies avec AFP le 23 juillet 2025

Le géant norvégien de l'énergie Equinor a annoncé mercredi qu'il dépréciait de 955 millions de dollars un grand projet éolien au large de New York, Empire Wind, un temps bloqué par l'administration Trump en début d'année.

Le ministre américain de l'Intérieur Doug Burgum avait annoncé à la mi-avril avoir ordonné l'arrêt "immédiat" et jusqu'à nouvel examen des travaux de construction de la première phase d'Empire Wind, un ensemble de 54 turbines susceptibles d'alimenter 500.000 foyers à Brooklyn.

Il affirmait que ses prédécesseurs de l'administration Biden n'avaient pas effectué "d'analyse suffisante" sur le projet d'un coût évalué à 2,5 milliards de dollars.

Le ministre norvégien des Finances, l'ex-chef de l'Otan Jens Stoltenberg, avait notamment soulevé la question avec Kevin Hasset, le principal conseiller économique de Donald Trump, lors d'une visite officielle aux Etats-Unis.

Les autorités américaines étaient finalement revenues en mai sur leur décision de bloquer le projet.

"Nous continuons de faire progresser notre portefeuille dans les énergies renouvelables, et le projet Empire Wind 1 est de nouveau en phase d'exécution", a déclaré mercredi le directeur général d'Equinor, Anders Opedal, cité dans un communiqué.

Mais il a aussi fait état d'une dépréciation de 955 millions de dollars "due à des changements réglementaires" affectant les synergies des futurs projets éoliens en mer et à "une exposition accrue aux droits de douane".

Sur ce montant, 763 millions concernent le projet Empire Wind 1 et le terminal de South Brooklyn Marine, le reste étant lié au bail d'Empire Wind 2, la deuxième phase du projet.

Cette dépréciation a pesé sur les résultats du deuxième trimestre: le groupe a accusé une baisse de 29% de son bénéfice net sur un an, à 1,3 milliard de dollars.

Indicateur préféré d'Equinor, le résultat d'exploitation ajusté, qui gomme certains éléments exceptionnels, ressort à 6,5 milliards de dollars contre près de 7,5 milliards à la même période de l'an dernier.

Les performances ont aussi été affectées par le recul du prix du pétrole qui n'a pas suffi à compenser la hausse des prix du gaz naturel et l'augmentation de la production d'hydrocarbures, qui frôle les 2,1 millions de barils équivalent-pétrole par jour.

Equinor discovers gas at Skred prospect in Barents Sea
Preliminary estimates suggest the discovery holds between 0.3 and 0.5 billion standard cubic metres of recoverable gas, equivalent to 1.9 to 3.1 million barrels of oil.

Pradeep Bairaboina 11th Jul 2025

Equinor Energy, alongside its partners, has announced a gas discovery at the “Skred” prospect in Norway’s Barents Sea.

The well, located approximately 23km north of the 7220/8-1 discovery well on the Johan Castberg field and 210km northwest of Hammerfest, has revealed significant potential.

Preliminary estimates suggest the discovery holds between 0.3 and 0.5 billion standard cubic metres of recoverable gas, equivalent to 1.9 to 3.1 million barrels of oil.

The consortium plans to evaluate the possibility of integrating this discovery with the Johan Castberg field.

This marks the 15th exploration well in production licence 532, granted during the 20th licensing round in 2009. The COSLProspector drilling rig executed the drilling of well 7220/5-4.

The well aimed to identify petroleum in Middle Jurassic reservoir rocks, focusing on the Stø Formation as the primary target and the Nordmela Formation as the secondary target.

The well discovered a 14m gas column within the Stø Formation, comprising 70m of sandstone with favourable reservoir quality. The gas/water contact was identified at 1,849m below sea level.

Additionally, the lower part of the Nordmela Formation revealed gas in a 3m thick sandstone layer with moderate to good reservoir quality.

Above the primary target, a 14m sandstone layer from the Cretaceous was encountered, containing a 1-2m oil-filled zone in its lower section, though the reservoir quality was not optimal.

While the well was not subjected to formation testing, substantial data and samples were collected for analysis.

Drilled to a vertical depth of 2,144m below sea level, the well concluded in the Late Triassic Fruholmen Formation.

The site, with a water depth of 415m, will now see the well permanently plugged and abandoned.

Equinor : Developing the largest oil producer on the Norwegian continental shelf

europetrole le 01/07/2025

Equinor and its partners are investing NOK 13 billion in the third phase of Johan Sverdrup, one of the world’s most carbon-efficient oil fields. New subsea infrastructure will increase recovery by 40–50 million barrels of oil equivalent (boe).

“By building on the technologies, solutions, and infrastructure from phases 1 and 2 of Johan Sverdrup, we can carry out an efficient development with a rapid start-up of production. The project increases the recovery rate and value creation from Johan Sverdrup, one of the world’s most carbon-efficient oil and gas fields. At the same time, it contributes to stable energy supplies to Europe,” says Trond Bokn, senior vice president for project development in Equinor.

Increased value creation and innovation

The development includes two new subsea templates which will be tied into existing infrastructure via new pipelines. The investment will increase recoverable volumes from the field by 40–50 million boe, with production expected to start in the fourth quarter of 2027.

To ensure optimal resource utilisation, the project leveraged artificial intelligence to analyse field layouts and well paths. This technology has enabled faster decision-making and resulted in cost savings of NOK 130 million for the phase 3 project.

The project also facilitates future value creation at Johan Sverdrup by adding extra well slots, and opportunities for connecting additional subsea templates.

Contract awards

The Johan Sverdrup field contributes significantly to value creation and ripple effects in society and has driven important industrial development in Norway.

For the phase 3 project, TechnipFMC has been awarded the contract for engineering, procurement, construction, and installation (EPCI) for the subsea development, with a contract value of approximately NOK 5.3 billion. Additional contracts, including platform modifications and the drilling of eight wells, are planned to be awarded later in 2025.

Increased recovery and production

Safe and efficient operations at Johan Sverdrup are delivering results, with systematic efforts to maximise recovery. Phase 3 of the development will create additional value.

The expected recovery rate from Johan Sverdrup is already world-class at 66 percent. The phase 3 project is an important step towards achieving our ambition of 75 percent. The average for the Norwegian continental shelf (NCS) is 47 percent.

“In 2024, Johan Sverdrup set a production record with 260 million barrels of oil, the highest annual oil production ever from a Norwegian field. Every third barrel of oil from the Norwegian continental shelf now comes from the field. Phase 3 is an important contribution to maintaining high production from Johan Sverdrup in the years to come,” says Marianne Bjelland, vice president for Johan Sverdrup.

Equinor aims to maintain a high level of oil and gas production on the NCS towards 2035. Johan Sverdrup phase 3 is one of several projects receiving an investment decision this year that supports this ambition.

The partnership has submitted a notification to the authorities in accordance with the existing plan for development and operation (PDO). The notification is subject to governmental approval.

Johan Sverdrup phase 3:

- Location: Johan Sverdrup is located in the Utsira High area of the North Sea, 160 kilometres west of Stavanger, in water depths of 110–120 metres, covering an area of 200 square kilometres.
- Production capacity: 755,000 barrels per day, approximately one-third of Norway’s total oil production at current levels.
- Economic impact: In 2024, the operation of the Johan Sverdrup field alone contributed over 4,400 full-time equivalents and Norwegian deliveries worth NOK 7 billion.
- Electrification: Johan Sverdrup is powered by electricity from shore, with CO₂ emissions of 0.67 kilograms per barrel of oil produced – approximately 5% of the global average.
- Phase 3 development: Comprises two new subsea templates in the Kvitsøy and Avaldsnes areas with six well slots each, totalling eight wells (seven oil production wells and one water injection well), tied back to existing templates and pipelines to the P2 platform for processing and export.
- Future-proofing: The project enables future value creation by including extra well slots, spare capacity in the control cable, and opportunities for connecting additional subsea templates.
- Ownership interests: Equinor Energy AS 42.6267% (operator), Aker BP ASA 31.5733%, Petoro AS 17.36%, and TotalEnergies EP Norge AS 8.44%.

Equinor Hits New Discovery in Johan Castberg

by Jov Onsat|Rigzone Staff | Monday, June 30, 2025

Equinor ASA on Monday announced another discovery in the recently started-up Johan Castberg field on Norway’s side of the Barents Sea.

The majority state-owned energy major put preliminary estimates for well 7720/7-DD-1H, or Drivis Tubaen, at 9-15 million barrels of oil. The discovery was drilled near the Drivis discoveries of 2014, according to a press release by Equinor.

“The licensees will consider tie-in of the discovery to the Johan Castberg field”, said Equinor, which operates Johan Castberg with a 46.3 percent stake. The other developers are Eni SpA-backed Var Energi ASA with a 30 percent interest and state-owned Petoro AS with 23.7 percent.

“The Johan Castberg volume base originally estimated at 450-650 million barrels, our clear ambition is to increase the reserves by another 250-550 million barrels”, said Grete Birgitte Haaland, Equinor senior vice president for exploration and production North. “To realize this, we are planning six new exploration wells and continuous exploration activity”.

Earlier this month Equinor said Johan Castberg has ramped up to capacity, or 220,000 barrels of oil per day, after going onstream late March.

“This increases energy deliveries from the Barents Sea by 150 percent”, Equinor said in a statement June 20.

Johan Castberg is the third field developed in the Norwegian Barents Sea after Snohvit, which started production 2007, and Goliat, which went online 2016.

"Johan Castberg represents a gamechanger for the importance of the Barents Sea for Norway's future as an energy nation. Every three to four days, tank loads now depart from Johan Castberg, each of them worth around half a billion Norwegian kroner”, Kjetil Hove, Equinor executive vice president for Norwegian exploration and production.

“The field will remain on stream for at least 30 years, delivering stable energy to Europe, generating high value for Norway, and ripple effects and jobs in Northern Norway”.

The new discovery was made in a new segment called the Tubaen formation 1,769 meters (5,803.81 feet) below the seabed. The well had a water depth of 345 meters, Equinor said.

Drivis Tubaen is the 14th exploration well drilled in production license 532, awarded 2009, according to Equinor.

The well was drilled by the Transocean Enabler rig as an extension from a production well. The rig remains in Johan Castberg for further drilling, Equinor said.

“The Barents Sea is the least explored ocean area on the Norwegian continental shelf”, it said. “With the Johan Castberg's production facilities in place, it becomes more attractive to explore the neighboring areas.

“Going forward, two rigs will drill both production wells and new exploration wells in the areas around Johan Castberg and Goliat. Equinor will drill one to two exploration wells annually around Johan Castberg”.

Equinor signe un accord de fourniture de gaz au Royaume-Uni pour près de 24 milliards d'euros

Connaissance des Énergies avec AFP le 05 juin 2025

Le groupe énergétique norvégien Equinor a annoncé jeudi avoir conclu un accord d'une valeur estimée à 20 milliards de livres (24 milliards d'euros), au cours actuel, avec le britannique Centrica, maison mère de British Gas, pour la fourniture de gaz naturel au Royaume-Uni jusqu'en 2035.

Près de 10% des besoins annuels du Royaume-Uni
L'accord de long terme signé par les deux groupes prévoit la livraison annuelle d'environ 5 milliards de m3 de gaz sur dix ans, à compter du 1er octobre, soit de quoi couvrir près de 10% des besoins annuels du Royaume-Uni, a indiqué Equinor dans un communiqué.

En 2011, Centrica avait déjà conclu un accord de dix ans avec Equinor (alors appelé Statoil) qui prévoyait la fourniture, à compter de 2015, de 5 milliards de m3 par an, un volume annuel ensuite relevé à 7,3 milliards de m3.

La Norvège, et Equinor en premier lieu, est aujourd'hui le principal fournisseur de gaz des Britanniques, couvrant près des deux tiers de leurs besoins.

Cet hiver, Centrica, maison mère de British Gas, principal distributeur du Royaume-Uni, s'était alarmé "des niveaux inquiétants" des réserves de gaz du pays, une situation reflétant aussi celle observée en Europe continentale.

Contribuer à la sécurité énergétique du Royaume-Uni
"Cet accord continuera de contribuer à la sécurité énergétique du Royaume-Uni grâce à des approvisionnements fiables en gaz provenant du plateau continental norvégien", a fait valoir le directeur général d'Equinor, Anders Opedal, cité dans le communiqué. "La flexibilité offerte par le gaz naturel jouera un rôle clé pour permettre le développement accru des énergies renouvelables et la décarbonation au Royaume-Uni", a-t-il affirmé.

Selon l'Agence internationale de l'énergie, le gaz naturel représente 38% de l'offre énergétique totale du Royaume-Uni, ce qui en fait sa principale source d'énergie.

En raison de sa dépendance aux importations, le pays avait été frappé de plein fouet par la crise énergétique provoquée par l'invasion à grande échelle de l'Ukraine par la Russie en février 2022, laquelle s'était traduite par une hausse durable des factures pour les consommateurs britanniques.

Également cité dans le communiqué, le directeur général de Centrica, Chris O'Shea, a de son côté souligné que l'accord "ne garantit pas seulement une meilleure sécurité énergétique du Royaume-Uni, mais il ouvre aussi la voie au développement d'un marché de l'hydrogène en plein essor".

Fin 2023, Equinor avait aussi signé un accord avec l'allemand SEFE prévoyant la fourniture d'environ 10 milliards de m3 de gaz par an à l'Allemagne entre 2024 et 2034, avec une option pour cinq ans supplémentaires. La presse norvégienne avait alors évalué la transaction à près de 52 milliards d'euros aux cours et taux de change d'alors.

Equinor vend sa part dans un champ pétrolier brésilien pour 3,5 milliards de dollars

AFP le 02 mai 2025

Le groupe énergétique norvégien Equinor a annoncé vendredi la vente de sa participation de 60% dans le champ pétrolier brésilien de Peregrino pour 3,5 milliards de dollars au groupe brésilien Prio.

"Cette opération s'inscrit dans le cadre des efforts constants déployés par Equinor pour améliorer son portefeuille international par le biais de cessions et d'acquisitions d'actifs", a déclaré Philippe Mathieu, dirigeant d'Equinor responsable de l'exploration/production à l'international cité dans un communiqué.

Equinor exploite le champ offshore de Peregrino depuis 2009 et y a produit environ 300 millions de barils de pétrole. Ce champ de pétrole lourd est situé dans le bassin de Campos, au large de Rio.

Prio, plus grand groupe pétrolier et gazier indépendant du Brésil, avait déjà repris l'an dernier les 40% de ce champ détenus par le conglomérat chinois Sinochem.

Equinor indique qu'il va concentrer ses efforts au Brésil sur le champ gazier Raia et sur le démarrage du champ pétrolier en eaux profondes Bacalhau.

TechnipFMC secures iEPCI contract for Johan Sverdrup Phase 3 expansion
The company will design, manufacture, and install subsea production systems, umbilicals, and rigid pipelines, connecting new subsea templates to the existing Johan Sverdrup field infrastructure

Swagath Bandhakavi 25th Mar 2025

TechnipFMC has secured an integrated engineering, procurement, construction, and installation (iEPCI) contract from Equinor for the third phase of development at the Johan Sverdrup field in the Norwegian North Sea.

The contract, classified as “large” by TechnipFMC, is valued between $500m and $1bn and will be recorded in the company’s first-quarter 2025 order intake.

The Johan Sverdrup field with estimated resources of 2.7 billion barrels of oil equivalent, is one of the most significant offshore oil developments on the Norwegian continental shelf.

The Phase 3 expansion is intended to connect additional wells to existing infrastructure, which is powered by electricity from onshore sources.

TechnipFMC’s scope of work includes the design, manufacture, and installation of subsea production systems, umbilicals, and rigid pipelines, integrating new subsea templates into the existing field centre.

The contract follows an integrated front-end engineering and design (iFEED) study, which helped define the project’s technical requirements.

TechnipFMC subsea president Jonathan Landes said: “It is a privilege to contribute once again to the development of this field, where we delivered subsea production systems for each of the previous phases. We are excited to leverage our iEPCI integrated execution model to further enhance this world-class offshore asset.”

Johan Sverdrup, which is the third-largest oil field on the Norwegian continental shelf, is operated by Equinor with a 42.63% stake. Aker BP (31.6%), Petoro (17.36%), and TotalEnergies EP Norge (8.44%) are the other stakeholders.

Production from Johan Sverdrup Phase 2 commenced in December 2022, introducing a new platform, five additional subsea systems, 28 wells, and an upgraded riser platform. The expansion also extended the project’s shore-to-sea power transmission to the Utsira High area.

The initial phase of the field began production in October 2019.

Equinor Starts Gas Production at Halten East

by Jov Onsat|Rigzone Staff | Tuesday, March 18, 2025

Equinor ASA has put the Halten East field in the Norwegian Sea onstream, unlocking new natural gas for Europe.

“We are starting up Halten East at a time where piped gas from Norway is in high demand and important for energy security”, Geir Tungesvik, executive vice president for projects, drilling and procurement at Equinor, said in a company statement Monday.

“In a challenging cost and inflation environment, the project has been delivered both on time and within our cost estimate”.

Halten East, a tie-in to be developed in two phases, holds about 100 million barrels of oil equivalent recoverable reserves, according to the Norwegian majority state-owned energy company.

The development, which has an estimated investment of NOK 9 billion ($857.81 million), targets six discoveries and potentially three more prospects. It uses existing infrastructure deployed for Åsgard, another Equinor-operated field that started up 1999.

Phase 1 of Halten East consists of six wells in five discoveries. So far the first well, Gamma, has begun production. “The second phase is planned in 2029”, Equinor said. Phase 2 plans to add a sidetrack and potentially three more wells.

The gas will be sent to the Kårstø terminal, from which it will be shipped via pipeline to European buyers.

In the third quarter of 2024 Norway continued to be the European Union’s top pipeline gas supplier with a share of 47 percent, according to the European Commission’s latest quarterly gas market report, published December 20, 2024. Norway has been the EU's number 1 gas source since the latter half of 2022, months after Russia invaded Ukraine, according to Commission data.

“Halten East demonstrates the importance of area solutions and cooperation between license owners and authorities to realize the full resource potential on the Norwegian continental shelf”, commented Kjetil Hove, Equinor executive vice president for development and production on Norwegian waters.

Equinor operates Halten East with a 69.5 percent stake, having acquired Sval Energi AS’ 11.8 percent interest November 2024. The partners are local players Vår Energi ASA with a 24.6 percent stake and Petoro AS, owned by the Norwegian state, with 5.9 percent.

Equinor also holds an operating stake of 35.01 percent in Åsgard. Petoro owns 34.53 percent, Var Energi 22.65 percent and TotalEnergies SE 7.81 percent.

“Together, we can develop industrial solutions that will continue to deliver energy with low costs and low emissions”, Hove added. “We have a large portfolio of projects that will connect discoveries to our producing hubs. Equinor expects to put over 30 such projects on stream at the NCS [Norwegian continental shelf] within 2035”.

Norway-based suppliers have bagged around 90 percent of Halten East investments, Equinor noted, adding: “The development phase of Halten East is estimated to provide around 3000 person-years of employment per year from 2022 to 2029”.

Equinor baisse ses ambitions dans les énergies renouvelables

AFP le 05 février 2025

Après un recul de ses résultats annuels, le géant norvégien de l'énergie Equinor a annoncé mercredi une baisse de ses ambitions dans les énergies renouvelables et une hausse de sa production d'hydrocarbures.

Hausse de plus de 10% de la production de pétrole

Le groupe, qui visait jusqu'à présent entre 12 et 16 gigawatts (GW) de capacité dans les énergies renouvelables en 2030, a ramené cette fourchette à entre 10 et 12 GW.

Malgré l'urgence climatique, Equinor, comme beaucoup de ses pairs, rechigne à sacrifier ses juteuses activités dans les hydrocarbures au profit des énergies renouvelables, notamment l'éolien en mer, beaucoup moins rentables, voire déficitaires.

Le groupe renonce ainsi à son objectif de consacrer la moitié de ses investissements bruts à ce secteur d'ici à 2030. En revanche, il prévoit une hausse de plus de 10% de sa production de pétrole et de gaz entre 2024 et 2027.

L'an dernier, sa production d'hydrocarbures s'est élevée à 2,07 millions de barils équivalent-pétrole par jour (Mbep/j), en légère baisse (-1%) par rapport à l'année précédente. Pour 2030, l'objectif a été revu à la hausse avec une production attendue autour de 2,2 Mbep/j contre environ 2 Mbep/j prévus jusqu'à présent.

Un bénéfice net en recul de 26% en 2024

Parallèlement, le groupe prévoit de consacrer 9 milliards de dollars à la rémunération de ses actionnaires cette année.

Equinor a fait ces annonces lors de la présentation de ses résultats annuels.

Après des années fastes liées à l'envolée des prix de l'énergie, son bénéfice net a reculé de 26% en 2024, à 8,8 milliards de dollars, un niveau qui reste cependant historiquement élevé.

Indicateur préféré d'Equinor, le résultat d'exploitation ajusté, qui gomme certains éléments exceptionnels, a frôlé les 30 milliards de dollars l'an dernier, en baisse de 18%.

Énergie : Equinor annonce une coupe dans ses effectifs dédiés au renouvelable

Agence Ecofin 22 nov 2024

Bien qu’elles se soient engagées à promouvoir les énergies renouvelables, de plus de plus de compagnies pétrolières semblent sortir ce segment de leurs priorités pour maximiser leur rentabilité.

La multinationale norvégienne Equinor, présente en Algérie, en Angola, en Libye, au Nigeria et en Tanzanie, compte réduire de 20 % les effectifs de sa division « Énergies renouvelables ». Une décision qui devrait se traduire par la suppression d’environ 250 postes à temps plein.

Selon des informations publiées jeudi 21 novembre, cette décision va principalement affecter les activités dans le segment de l’éolien offshore qui représente une part significative des opérations mises en œuvre par Equinor dans le domaine des énergies renouvelables.

La compagnie explique ce choix par la hausse des coûts, et des défis liés à la chaîne d’approvisionnement qui ont affecté ce secteur. Son bilan trimestriel indique un « résultat d’exploitation ajusté de la division Énergie renouvelable négatif de 115 millions $ » avec des « coûts de développement des projets supérieurs aux profits des actifs en exploitation ».

Une politique qui prend de l’ampleur chez les pétroliers 

Bien qu’Equinor compte malgré tout poursuivre son objectif visant à atteindre une capacité installée de 12 à 16 gigawatts en matière d’énergies renouvelables d’ici à 2030, l’entreprise réduit quelque peu le niveau de priorité accordé à ces dernières jusqu’ici.

L’entreprise n’est d’ailleurs pas la première et la seule à avancer dans cette direction. D’autres multinationales comme l’Anglo-Néerlandaise Shell et la Britannique BP, ont également réduit leurs activités liées aux énergies renouvelables et à la réduction des émissions de carbone.

Des choix qui interviennent alors que les experts, notamment ceux de Wood Mackenzie, s’accordent à dire que les investissements mondiaux dans les énergies vertes doivent atteindre 3500 milliards de dollars par an pour atteindre zéro émission nette de CO2 d’ici 2050.