Equinor Energy AS and partners will invest more than 4 billion krone ($400 million) in a new subsea development to increase gas production from Troll field in the North Sea. The Troll West Increased gas recovery North (TWIN) expansion—the third step of Troll Phase 3, which produces gas from the Troll West reservoir—could come online as early as 2028, said Gunnar Nakken, Equinor’s senior vice-president for projects and subsea Norway. TWIN is expected to contribute around 11 billion standard cu m of gas. “By simplifying, increasing standardization and reusing existing infrastructure and equipment, we are reducing costs and enabling faster production,” he said. Equinor aims to produce 1.3 million b/d from the Norwegian Continental Shelf (NCS) in 2035 to meet a portion of Europe’s energy needs. Troll field contains about 40% of NCS total gas reserves, with gas from Troll meeting around 10% of Europe’s gas needs. The TWIN project consists of two wells in a template and a pipeline connected to existing subsea infrastructure. The umbilical and MEG line will be extended to the new development. The second step of Troll Phase 3 is expected to come online this year, continuing production from Troll A platform, 80 km northwest of Bergen, Norway, and the Gassco-operated Kollsnes processing plant towards 2030, Equinor said. Equinor is operator of the project with 30.55% interest. Partners are Petoro AS (55.93%), A/S Norske Shell (8.19%), TotalEnergies EP Norge AS (3.69%), and ConocoPhillips Skandinavia AS (1.64%).

The proposed 7.5-million tonne/year (tpy) Zululand Energy Terminal (ZET) at the Port of Richards Bay, South Africa, has invited expressions of interest (EOI) from engineering, procurement and construction (EPC) contractors for development of planned LNG regasification infrastructure. Imported natural gas is expected to supply both industry and power generation. Phase 1 of the project will use a 170,000-cu m floating storage unit attached to 3 million tpy of onshore regasification capacity. Phase 2 will add 220,000 cu m of onshore storage (potentially replacing the FSU) and 4.5 million tpy of regasification.  ZET hopes to complete detailed engineering during 2027 to reach final investment decision in 2028 and start operations in 2030. Reuters reported last week that ExxonMobil Corp. had signed a preliminary deal to supply LNG to ZET. Developed as a joint between Vopak Terminal Durban and Transnet Pipelines, ZET project is expected to be South Africa’s first LNG terminal. The consortium will design, develop, construct, finance, operate, and maintain the terminal in the South Dunes Precinct at the Port of Richards Bay over a 25-year concession. EPC execution will be subject to ZET’s localization and economic development objectives. Successful contractors will be expected to support local supplier participation, skills development, and the use of local labor. Qualifying parties will be included in the project’s vendor database and may be shortlisted for subsequent phases as potential preferred contractors or subcontractors. The EOI submission window closes July 9, 2026. Interested contractors are invited to access the full EOI documentation here. South African utility Eskom and ZET earlier this month signed a head of agreement (HOA) establishing the framework for a long-term strategic partnership to support South Africa’s gas-to-power program, underpinning a planned 3-Gw power plant near the terminal in KwaZulu-Natal. Vopak Terminal Durban is owned by Royal Vopak and Reatile Group

REDUC’s fist soybean oil-based SAF sale Announcement of FID on the RPBC renewables plant followed Petrobras’ June 17 confirmation that its 239,000-b/d Duque de Caxias (REDUC) refinery in the Baixada Fluminense area of Rio de Janeiro had completed first production and sale of a first 3,800-cu m batch of SAF made from soybean oil certified under the CORSIA low Land Use Change (ILUC) risk standard, which verifies sustainability criteria and a lower risk of impact on new land areas. Produced via co-processing and featuring 1% renewable content, the SAF batch marked “commercialization of the world’s first SAF made from certified low-ILUC-risk soy [to demonstrate] Petrobras’s commitment to sustainability, the energy transition, and the development of products aligned with market and societal demands [for lower-carbon solutions],” said Angélica Laureano, Petrobras’ director of logistics, sales, and markets. In October 2025, the REDUC refinery secured Brazil’s first international approval to advance commercial-scale production of SAF via the hydroprocessed esters and fatty acids (HEFA) co-processing route complying with ISCC System GmbH’s International Sustainability Carbon Certification (ISCC) standards, validating that SAF produced at the site meets the highest international sustainability and lifecycle carbon emission standards. Developed under ICAO’s CORSIA, the ISCC CORSIA certification was a prerequisite for commercial-scale SAF production following rigorous assessment of the production’s lifecycle carbon emissions and traceability. Equipped to produce as much as 10,000 b/d of SAF using a blend of conventional petroleum and up to 1.2% renewable feedstock, REDUC’s integration of bio-based oils—such as vegetable oil—into existing refining infrastructure via the HEFA co-processing method allows the refinery to produce SAF alongside conventional jet fuel with minimal investment, Petrobras previously said.

Equinor Energy AS and partners will invest about NOK 4 billion ($410 million) in the new Troll West increased gas recovery north (TWIN) subsea development in Troll field in the North Sea. The TWIN project consists of two wells in a template and a pipeline connected to existing subsea infrastructure. The umbilical and monoethylene glycol line will be extended to the new development. The project is expected to contribute about 11 billion std cu m of gas to Troll. It is the third step of Troll Phase 3, which produces gas from the Troll West reservoir. Recoverable reserves from Troll Phase 3, mainly gas, are estimated at 2.2 billion boe. In accordance with the Petroleum Act, the partnership will now send an announcement to the Ministry of Energy concerning the development. An environmental impact assessment has been carried out. Troll, which supplies as much as 10% of Europe’s daily demand for gas, contains about 40% of the total gas reserves on the Norwegian continental shelf and was developed in phases, with gas extraction from Troll Øst in Phase 1 and oil from Troll West in Phase 2. The oil in Troll West is produced from multiple subsea templates tied into Troll B and Troll C via pipelines. Production from the Troll C installation started in 1999. Troll C is also used for production from Fram, Fram H-Nord, and Byrding. Several amended development plans were approved in connection with installing multiple subsea templates on Troll West. Equinor Energy AS is operator of TWIN (30.55%) with partners Petoro AS (55.93%), A/S Norske Shell (8.19%), TotalEnergies EP Norge AS (3.69%), and ConocoPhillips Skandinavia AS (1.64%).

Despite a slowdown in headline deal values this spring, upstream mergers and acquisitions remain active beneath the surface. In this ICYMI episode of the Oil & Gas Journal ReEnterprised podcast, Mikaila Adams, managing editor, examines data from Enverus and Rystad Energy detailing international and North American upstream deal markets in 2025 and into 2026. The discussion explores how pricing uncertainty widened the gap between buyers and sellers, creating a temporary pause rather than a collapse in market activity. The episode also looks at where capital continues to flow and what those trends reveal about the industry’s direction. From North American consolidation led by the Devon Energy–Coterra Energy merger to continued interest in gas-weighted assets tied to Gulf Coast LNG exports, the analysis highlights the forces shaping today’s upstream M&A landscape. It also considers the likelihood of additional divestitures, private equity activity, and asset sales as companies refine their portfolios, pointing to continued dealmaking momentum even in a more volatile market. References Devon, Coterra joining forces to create 1.6 million boe/d shale titan https://www.ogj.com/general-interest/companies/news/55354563/devon-coterra-joining-forces-to-create-16-million-boe-d-shale-titan Ovintiv to divest Anadarko assets for $3 billion https://www.ogj.com/general-interest/companies/news/55358241/ovintiv-to-divest-anadarko-assets-for-3-billion Insights: Vaca Muerta’s scale, productivity—and why it has more to give https://www.ogj.com/home/podcast/55370296/insights-vaca-muertas-scale-productivityand-why-it-has-more-to-give Mitsubishi to enter US shale gas business through Haynesville asset acquisition https://www.ogj.com/general-interest/companies/news/55344199/mitsubishi-to-enter-us-shale-gas-business-through-haynesville-shale-acquisition Shell to expand Canadian operations with $16.4-billion acquisition of ARC Resources https://www.ogj.com/general-interest/companies/news/55373597/shell-to-expand-canadian-operations-with-164-billion-acquisition-of-arc-resources US upstream M&A hits $38 billion in 1Q26 before volatility temporarily pauses the market https://www.enverus.com/newsroom/u-s-upstream-ma-hits-38-billion-in-1q26-before-volatility-temporarily-pauses-the-market/ International upstream M&A stuck at historic low https://www.enverus.com/newsroom/international-upstream-ma-stuck-at-historic-low/ Upstream deal value falls 83% as oil price uncertainty widens the buyer-seller gap https://www.rystadenergy.com/insights/upstream-deal-value-falls Iran war impact on global oil markets https://www.ogj.com/IranWar

When Gaspar announced the $22 billion deal for Coterra in February, investors and analysts quickly began to question the future of the Marcellus assets that had been under Coterra’s umbrella. Activist investor Kimmeridge had been calling for Coterra’s board to divest that asset and focus on the Delaware, a push that has since landed on Gaspar’s desk and one the executive has repeatedly said will be addressed via a broader review of the enlarged Devon’s holdings. Several times during his chat with Jayaram, Gaspar touted Devon’s prowess in the Delaware—adding Coterra’s operations has grown its footprint there to nearly 750,000 acres—and delineated the review process as covering three main points. What’s the value of the various assets on their own? What’s the market for them and who might the strategic and financial buyers be? (Here, Gaspar specifically mentioned asset-backed securitization (ABS) money “that’s really entered the space.”) And thirdly, and “very fundamentally important,” how complementary are the individual business units to each other? Could discerning observers interpret the latter as suggesting that the Marcellus assets are indeed the odd duck in the group, as Kimmeridge has said? (See the map above.) And is the ABS reference more than a winking acknowledgment of a Reuters report a month ago that money manager Stone Ridge Asset Management had bid $8 billion for the Marcellus division using securitization as a big financial lever? Gaspar didn’t elaborate and Jayaram didn’t press the issue. But Gaspar emphasized that clarity around the review isn’t far away: “We’ve telegraphed this is more of a months exercise, not a years exercise. […] The view with which we are approaching this, we are aggressive. We will be mindful of how do we take this moment in time to create more value for the shareholders.”