SBM Offshore awarded contracts for the GranMorgu field development

SBM Offshore announces that it has been awarded contracts for the GranMorgu field development project located in Block 58 in Suriname by the Operator, TotalEnergies EP Suriname B.V., an affiliate of TotalEnergies. Under these contracts, SBM Offshore will, in partnership with Technip Energies, construct and install a Floating Production, Storage and Offloading vessel (FPSO). The award follows completion of front-end engineering and design studies, and the final investment decision on the project by the Joint Venture operated by TotalEnergies EP Suriname B.V. SBM Offshore is expected to operate the unit under an operations and maintenance agreement.

The GranMorgu project is the first development within Block 58, circa 150 kilometers offshore Suriname. TotalEnergies is the operator holding a 50 percent interest in Block 58, alongside APA Corporation. Staatsolie has announced its intent to exercise its option to enter the development project with up to 20% interest.

The FPSO will be the first large deepwater project development in Suriname with an expected production capacity of up to 220,000 barrels of oil per day and associated gas treatment capacity of up to 500 million cubic feet per day. The FPSO will be spread moored in water depth of about 400 meters and will be able to store around 2 million barrels of crude oil. First oil is expected in 2028.

Thanks to the joint expertise of Technip Energies and SBM Offshore, this all-electric drive FPSO will also be designed to eliminate routine flaring, in line with TotalEnergies objectives and SBM Offshore’s goal to deliver carbon efficient units.

FPSO Maria Quitéria starts operating in the pre-salt Campos Basin

The Maria Quitéria platform ship produced its first oil on Tuesday (10/15) in the Jubarte field, pre-salt in the Espírito Santo portion of the Campos Basin. The unit can produce up to 100,000 barrels of oil a day and process up to 5 million cubic meters of gas. It will be interconnected to a total of eight producing wells and eight injectors.

FPSO Maria Quitéria's entry was brought forward; it was initially scheduled for 2025, according to the 2024-2028 Strategic Plan. Petrobras is the sole holder of the production rights for the Jubarte field, located in the area known as Parque das Baleias in Espírito Santo.

The platform is FPSO (floating production, storage, and transfer system). It is equipped with technologies to reduce emissions with greater operational efficiency and a reduction of around 24% in operational greenhouse gas emissions.

With a height of 156 meters and a length of 333 meters, the FPSO is installed at a water depth of 1,385 meters. It will also have the capacity to generate 100 MW of energy to supply a city of 230,000 inhabitants.

Parque das Baleias Integrated Project

The Parque das Baleias area is made up of the Jubarte, Baleia Anã, Cachalote, Caxaréu, Pirambú and Mangangá fields. The first field, Jubarte, was discovered in 2001. In 2019, Petrobras and the National Agency of Petroleum, Natural Gas and Biofuels (ANP) signed an agreement to extend the concession period until 2056 for the new unified Jubarte field, which enabled the implementation of FPSO Maria Quitéria, the latest production system for the Parque das Baleias Integrated Project, as well as complementary projects in the area.

Three other platforms operate in Parque das Baleias: P-57, P-58, and FPSO Cidade de Anchieta. When Maria Quitéria starts operating at full load, this unit will account for around 40% of the field's production.

TechnipFMC Awarded iEPCI™ Contract for bp’s Greenfield 20K Development in the Paleogene

TechnipFMC (NYSE: FTI) has been awarded an integrated Engineering, Procurement, Construction, and Installation (iEPCI™) contract(1) by bp for its greenfield Kaskida development in the Gulf of Mexico.

The contract covers the design and manufacture of subsea production systems, including 20,000 psi (20K) standardized subsea trees and manifolds. The scope also includes the design, manufacture, and installation of subsea umbilicals, risers, and flowlines.

The award follows an integrated Front End Engineering and Design (iFEED®) study by TechnipFMC.

Jonathan Landes, President, Subsea for TechnipFMC, commented: “Our innovative high-pressure solutions are key to helping unlock the most economically attractive opportunities in the Paleogene. Kaskida is our latest iEPCI™ project with bp and is emblematic of our longstanding collaboration. Through early engagement, we’re leveraging the breadth of our technological and integration capabilities to help bp successfully deliver Kaskida.”

Shell invests in water injection at Gulf of Mexico field

Shell Offshore Inc. (Shell), a subsidiary of Shell plc, has taken a Final Investment Decision (FID) on a ‘waterflood’ project at its Vito asset in the US Gulf of Mexico. Water will be injected into the reservoir formation to displace additional oil.

The process is due to begin in 2027 and is expected to significantly enhance volume capacity at the Vito field.

“Over time, we’ve seen the benefits of waterflood as we look to fill our hubs in the Gulf of Mexico,” said Zoë Yujnovich, Shell Integrated Gas and Upstream Director. “This investment will deliver additional high-margin, lower-carbon barrels from our advantaged Upstream business while maximizing our potential from Vito.”

Waterflood is a method of secondary recovery where the injected water physically sweeps the displaced oil to adjacent production wells, while re-pressurizing the reservoir. The three water injection wells were all drilled as pre-producers.

Shell is the leading deep-water operator in the U.S. Gulf of Mexico, where our production has among the lowest greenhouse gas (GHG) intensity in the world for producing oil.

Notes to editors

• In July 2009, the Vito field was discovered in more than 4,000 feet of water approximately 75 miles south of Venice, LA, 150 miles southeast of New Orleans and 10 miles south of the Shell-operated Mars TLP.
• In 2015, the original Vito host design was simplified and rescoped, resulting in a reduction of approximately 80% in CO2 emissions over the lifetime of the facility as well as a cost reduction of more than 70% from the original host design concept.
• Shell (Operator 63.11%) and Equinor (36.89%) announced FID for the Vito development in April 2018, with first oil achieved in February 2023.
• Given the properties of the Vito reservoir, energy is required to maximize the producing rate of existing wells and thus ultimate recovery.
• The Vito waterflood project will increase recoverable resource volume by 60 million boe. The estimate of resources volumes is currently classified as 2P and 2C under the Society of Petroleum Engineers’ Resource Classification System.
• The reference to our U.S. Gulf of Mexico production having among the lowest GHG intensity in the world is a comparison among other IOGP oil-and gas-producing members.
• As communicated at Shell’s Capital Markets Day in 2023, we plan to see production stabilise at 1.4 million barrels per day of liquids to 2030.

McDermott Secures EPCI Contract for Gas Project Offshore Trinidad and Tobago

McDermott has been awarded an engineering, procurement, construction, installation (EPCI), hook up and commissioning contract by Shell Trinidad and Tobago Limited for the Manatee gas field development project, located 60 miles (100 kilometers) off the southeast coast of Trinidad and Tobago.

The award follows the successful delivery of the front-end engineering design, detailed engineering and long lead procurement service contracts for the project's initial design and execution planning.

Under the contract scope, McDermott will design, procure, fabricate, hook up and commission a platform and jacket. The company will also provide design, installation, and commissioning services for a 32-inch gas pipeline that will connect the platform to a gas processing facility operated by Shell. The contract scope also includes design, procurement, installation, and testing services for a fiber optic cable.

"This award leverages our unique, integrated EPCI capabilities and legacy of engineering excellence and innovation to successfully deliver large offshore platforms and complex subsea infrastructure worldwide," said Mahesh Swaminathan, McDermott's Senior Vice President, Subsea and Floating Facilities. "The Manatee project builds on our track record of successful project execution for Shell and exemplifies our commitment to building energy infrastructure required to meet demand."

This contract award also demonstrates our continued commitment to working in Trinidad and Tobago to support the future supply of gas to its domestic and export market.

SBM Offshore awarded FSO contract for Woodside’s Trion development

SBM Offshore is pleased to announce that it has signed a contract with Woodside Petróleo Operaciones de México, S. de R.L. de C.V. (“Woodside”), operator of the Trion deepwater oil field development located in the Perdido Belt of the western Gulf of Mexico. Under this contract, SBM Offshore will construct and thereafter lease to Woodside a Floating Storage and Offloading (“FSO”) unit for a period of 20 years. This award complements the Transportation & Installation contract for the FSO and the FPU awarded to SBM Offshore in 2023.

The new build FSO, based on a Suezmax-type hull, will be equipped with a Disconnectable Turret Mooring (“DTM”) system designed by SBM Offshore. The FSO will be moored in water depth of about 2,500 meters and will be able to store around 950,000 barrels of crude oil.

The Trion field is located 180 km off the Mexican coastline and 30 km south of the US/Mexico maritime border. The Trion project is an alliance between Woodside (60%, Operator) and PEMEX Exploración y Producción (40%, non-Operator).

Viaro Energy signs agreement to take over Shell & ExxonMobil’s UK Southern North Sea assets

Viaro Energy (“Viaro”), the independent British energy company operating in the UKCS and the Netherlands North Sea, is pleased to announce that its main operating subsidiary RockRose Energy Limited signed an agreement with Shell U.K. Limited, a subsidiary of Shell plc (“Shell”), and Esso Exploration and Production UK Limited, a subsidiary of ExxonMobil Corporation (“ExxonMobil”), to acquire a full ownership interest in their Shell-operated UK Southern North Sea assets.

Pending regulatory approval, Viaro will acquire a portfolio consisting of 11 operated offshore assets and one exploration field (Shamrock; Caravel; Corvette; Brigantine; Leman; Galleon; Skiff; Carrack Main, Cutter, Carrack East; Barque; and Clipper), all tying back to the Shell-operated onshore Bacton Gas Processing Terminal via the Leman and Clipper fields. In 2023, production was around 28,000 boepd (c. 5% of UK total gas production) and the assets possess strong growth potential through identified near field exploration opportunities.

With a strong record of reliable production and around 90% production efficiency reported, the natural gas fields of the Southern North Sea and the Bacton gas terminal have been part of the UK’s energy foundation for 56 years. The tight gas development ongoing in the Galleon and Barque fields and strong potential for tight gas opportunities and near field exploration already identified in the Greater Sole Pit area are both indicative of the fields’ lasting importance for the UK’s energy security.

Viaro estimates place the 2P volumes of these assets at 58 million barrels of oil equivalent (“boe”), with a projected potential to extract over 120 million boe of net 2C resources. Viaro intends to maximise the economic return of these assets and, by working to ensure the extraction is conducted to reach their fullest potential, to increase low-emissions production of gas in the area through a redevelopment with an existing infrastructure.

The Bacton Gas Processing Terminal provides a direct route for natural gas produced from the Southern and Central North Sea to the UK National Transmission system, operated by the National Grid, enabling gas to flow between the UK and the Netherlands. In recent years, it received the Bacton Rejuvenation Investment of around £300 million to upgrade and extend the life of the terminal for future use. Bacton gas is used to generate around 40% of Britain’s electricity and it constitutes the main supply of gas for East Anglia and North London’s homes and businesses, whose terminal optimisation potential has been recognised by the North Sea Transition Authority (“NSTA”).







With a well-established value chain, the Bacton gas terminal complex also holds immense potential to become an energy transition hub. According to the NSTA, the Bacton terminal is ideally positioned to become a significant hydrogen production site for London and the Southeast, with strong potential to play a role with carbon capture storage and offshore wind developments that can supply renewable power to Bacton. In addition, Viaro intends to conduct feasibility studies on the best ways to decarbonise this asset through the deployment of clean technology.







Francesco Mazzagatti, CEO of Viaro Energy, commented: “We are immensely grateful to the Shell and ExxonMobil teams for an exemplary collaboration on this major deal, which represents a crowning achievement of Viaro’s strategic vision in the North Sea to date. We have long emphasised our commitment to the UKCS North Sea, and while we have certainly encountered more than a few challenges to realise our initial strategy, it is deals like this that make it evident why it is a worthwhile long-term investment.







Shell and ExxonMobil’s Southern North Sea portfolio is not only the backbone of the UK’s energy production and security, but it also represents one of the best strategically placed solutions that have the potential to play an important role in the energy transition. With strong potential for wind farm synergies, electrification of upstream assets, CCS and hydrogen supply, this acquisition fits Viaro’s ongoing and planned activities across the energy sector perfectly.”