Trion Receives Regulatory Approval

The Trion field development plan (FDP) has been approved by the Mexican regulator, Comision Nacional de Hidrocarburos (CNH). Woodside’s final investment decision (FID) to develop the Trion resource, announced 20 June 2023, was subject to Trion joint venture approval and regulatory approval of the FDP.  Both of these conditions have now been met. 

Woodside CEO Meg O’Neill welcomed the approval of the FDP. 

“This milestone allows us to fully progress into execution phase activities with our contractors. “We look forward to working with PEMEX and our other stakeholders in Mexico to deliver this important project,” she said. 

Following the approval of the FDP, Woodside has booked Proved (1P) Undeveloped Reserves of 324.7 MMboe gross (194.8 MMboe Woodside share) and Proved plus Probable (2P) Undeveloped Reserves of 478.7 MMboe gross (287.2 MMboe Woodside share). 

The project execution phase activities are progressing and Woodside has executed key contracts relating to the development including: 

• the floating production unit (FPU) engineering, procurement and construction (EPC) contract with HD Hyundai Heavy Industries 
• the rig contract with Transocean 
• the FPU and floating storage offloading (FSO) installation contract with SBM Offshore 
• the subsea trees contract with OneSubsea UK. 

First oil is targeted for 2028. Woodside is operator of the Trion development with a 60% participating interest and PEMEX Exploración y Producción (PEMEX) holds the remaining 40%.

About Trion 

Trion is located in a water depth of 2,500 m, approximately 180 km off the Mexican coastline and 30 km south of the Mexico/US maritime border. Trion was discovered in 2012 by PEMEX. BHP Petroleum acquired an interest in 2017 which subsequently became part of Woodside’s portfolio in 2022. The resource will be developed through a FPU with an oil production capacity of 100,000 barrels per day. The FPU will be connected to a FSO vessel with a capacity of 950,000 barrels of oil. Crude is expected to be shipped to international markets and the development is expected to include 18 wells (nine producers, seven water injectors and two gas injectors) drilled in the initial phase, with a total of 24 wells drilled over the life of the Trion project. Gas that is not reinjected or used on the FPU will be delivered to the domestic natural gas pipeline network by a subsea gas pipeline. The forecast total capital expenditure is US$7.2 billion (US$4.8 billion Woodside share including capital carry of PEMEX of approximately US$460 million) including all 24 wells. 3

Petrobras signs closing of Golfinho and Camarupim Clusters

Petrobras, following up on the releases disclosed on 23/06/2022 and 24/06/2022, informs that, after fulfilling the precedent conditions set out in the binding contracts signed on 24/06/2022, it has today concluded the transfer of its entire stake in the sets of maritime concessions called Golfinho Cluster and Camarupim Cluster, in deep waters in the post-salt, located in the Espírito Santo Basin, to the company BW Energy Maromba do Brasil Ltda (BWE).

The transaction was concluded with payment at sight of US$12.2 million to Petrobras, including the adjustments provided for in the contract. The amount received today is in addition to the US$ 3 million paid to Petrobras when the contract was signed. In addition to this amount, Petrobras is expected to receive up to US$ 60 million in contingent payments, depending on future Brent prices and the development of the assets.

With the conclusion of the assignment, BWE takes on the role of operator of the maritime concessions contained in the Golfinho and Camarupim Clusters.

This disclosure is in accordance with Petrobras' internal rules and with the provisions of the special procedure for the assignment of rights to explore, develop and produce oil, natural gas and other fluid hydrocarbons, provided for in Decree 9.355/2018.

The fields transferred account for 6.6% of the production operated by Petrobras in the state of Espírito Santo, and their transfer does not impact Petrobras' other activities in the region, where the company maintains operations in important deepwater fields, such as Parque das Baleias, in addition to 6 exploratory areas. The company is maintaining its investment commitments in the state of Espírito Santo, with emphasis on the implementation of a new production unit in the Jubarte Field (FPSO Maria Quitéria) and the interconnection of new wells, projecting an increase in its production curve by 2027.

In addition to the offshore fields, Petrobras still has other operations in the state, such as the Cacimbas (UTGC) and Sul Capixaba (UTGSUL) natural gas processing units and the Barra do Riacho Waterway Terminal.

About Golfinho and Camarupim Clusters

The Golfinho Cluster is located in water depths between 1,300 m and 2,200 m, comprising the oil-producing Golfinho and non-associated gas-producing Canapu fields and the BM-ES-23 exploratory block.

The Camarupim Cluster is located in water depths between 100 m and 1,050 m, and includes the Camarupim and Camarupim Norte unitized fields, both of which produce non-associated gas.

Petrobras held a 100% stake in the Golfinho and Camarupim Clusters concessions, with the exception of exploratory block BM-ES-23, in which it held a majority stake of 65%, in partnership with Aquamarine Exploração Ltda (20%) and Inpex Petróleo Santos Ltda (15%). Petrobras was the operator in all the concessions.

The average total production of the Golfinho field in July 2023 was 10.2 thousand bpd of oil and 114.6 thousand m3/day of gas. The other areas are not in production.

About BWE

BWE is a wholly-owned subsidiary of BW Energy Ltd, an E&P company focused on low-risk oil reservoirs for development in phases and with access to existing production facilities.

Eni starts production from Baleine Field in Côte d’Ivoire with its partner PETROCI

Eni has today started production of oil and gas from the Baleine Field, located in the waters offshore Côte d’Ivoire. This milestone comes less than two years after the discovery in September 2021 and less than a year and a half after the Final Investment Decision. This marks the first emissions-free - Scope 1 and 2 - production project in Africa.

Baleine currently stands as the largest hydrocarbon discovery in Ivorian sedimentary basin. The fast time-to-market was made possible through Eni's phased development approach characteristic of recent projects, and along with its partner Petroci full collaboration. For the initial phase, production takes place through the Baleine FPSO, a refurbished and upgraded Floating Production Storage and Offloading unit capable of handling up to 15,000 bbl/d of oil and around 25 Mscf/d of associated gas. The start of Phase 2 is expected by the end of 2024 and will increase field production to 50,000 bbl/d of oil and approximately 70 Mscf/d of associated gas. The third development phase aims to elevate field production up to 150,000 bbl/d of oil and 200 Mscf/d of gas.

The entire gas production from the Baleine Field in this development phase and the subsequent ones will be delivered onshore through a newly constructed pipeline. This will enable the country to meet its domestic electricity market demands, facilitate energy access, and strengthen its role as a regional energy hub for neighboring countries.



The project leverages the best available technologies to minimize emissions. Residual emissions are offset through initiatives developed within the country, including supplying and distributing improved stoves to local communities, eliminating the need for wood or coal for cooking. The stove distribution program, initiated in 2022, is expected to reach over one million people in the next 6 years. Simultaneously, Eni has launched studies for Nature-Based Solutions projects covering 380,000 hectares of protected forests.

Eni's CEO, Claudio Descalzi, remarked, "The first oil from Baleine is a milestone in Eni's operations. Stemming from an extraordinary exploration success, we have achieved an industry-leading time-to-market of under 2 years from the declaration of commercial discovery. This outcome expresses the core principles of our strategy, encompassing Africa's pioneering net-zero project, accelerated development, local gas supply, and the promotion of a just transition".

In Côte d’Ivoire, Eni is engaged in a series of projects aligned with the Sustainable Development Goals (SDGs). Besides school refurbishment initiatives and workshops to enhance teacher skills benefiting around 8,500 students, a five-year agreement has been established with the Institut National Polytechnique Houphouët Boigny to train about 400 executives and technicians in the energy sector. Within the realm of community health, initiatives have been initiated to enhance access to healthcare services in 20 clinics located in vulnerable areas across different regions of the country. In the vocational training sphere, two projects have been launched for professional integration in the energy, automotive, and textile sectors, involving approximately 450 youths.

Eni's presence in Côte d’Ivoire dates back to the 1960s with Agip Côte d’Ivoire. Eni re-entered the country in 2015 and currently holds interests in the CI-101 and CI-802 blocks - where the Baleine field extends - as well as in four other deep-water Ivorian blocks: CI-205, CI-501, CI-401, and CI-801, all with the same partner, Petroci Holding.

TechnipFMC Awarded Significant Installation Contract by TotalEnergies for Girassol Life Extension Project

TechnipFMC (NYSE: FTI) has been awarded a significant(1) contract to install flexible pipe and associated subsea structures for the Girassol Life Extension project (GIR LIFEX) by TotalEnergies EP Angola and its Block 17 Partners.

The Company was previously awarded the engineering, procurement, and supply of subsea flowlines and connectors for GIR LIFEX last year.

Jonathan Landes, President, Subsea at TechnipFMC, commented: “The seamless integration of engineering, manufacturing, and installation provides our clients with the flexibility and agility they need to meet their project goals. We have good knowledge of this field, having built the subsea tree systems for the original Girassol development. It gives us immense pride that our long-term clients continue to show trust and confidence in our solutions through subsequent awards.”

(1) For TechnipFMC, a “significant” contract is between $75 million and $250 million.

Norwegian gas production increases on start-up of Dvalin field

Wintershall Dea has started production from the operated Dvalin gas field in the Norwegian Sea together with the partners Petoro and Sval Energi, providing significant new gas volumes to the European market.

The field helps underpin Norway’s position as Europe’s largest gas supplier: On plateau, Dvalin is planned to produce enough energy to heat more than 2 million homes. The additional volumes come as Europe continues to search for predictable long-term supplies of natural gas. “We are aware that in the winter months European demand for gas will rise, and the continent will be looking to Norway to be the supplier of choice. We have worked hard to ensure Dvalin will be onstream safely, and are satisfied that the field will make a significant contribution to European energy security,” said Dawn Summers, Wintershall Dea Chief Operating Officer.

The field has been shut-in since late 2020 after measurements of high levels of mercury in the well stream. Since then, mercury removal units have been installed at the onshore processing facilities at Nyhamna and Tjeldbergodden in mid-Norway.

“The team has worked hard to overcome technical challenges in the field, providing robust solutions that will allow Dvalin to deliver substantial gas volumes to our European partners long into the future,” said Michael Zechner Wintershall Dea Norge Managing Director.

The Dvalin field has an estimated lifetime until 2038 including the Dvalin North field, which is currently being developed.

GAS WEIGHTED PORTFOLIO AND SUBSEA STRATEGY STRENGTHENED

As a subsea gas field which is controlled from the nearby Heidrun platform, Dvalin helps maintain Wintershall Dea’s gas weighted portfolio, while supporting the broader strategy of producing hydrocarbons using existing infrastructure.

Located some 15 kilometres northwest of Heidrun, Dvalin has been developed using a single subsea template with four production wells. The field now joins Maria, Nova and Vega as Wintershall Dea’s fourth operated subsea field in Norway.

Additionally, it is the tie in point for the Wintershall Dea operated Dvalin North subsea gas development, which was approved by the Norwegian government in 2023.

BOOST FOR STRATEGIC GROWTH AREA

Located in the Haltenbanken area of the Norwegian Sea some 260 kilometres north of Kristiansund, and with expected recoverable gross reserves estimated at 113 million barrels of oil equivalent1 of which the majority will be gas, the Dvalin field lies at the heart of one of Wintershall Dea’s key growth regions. The company is partner and operator of several nearby exploration licenses, as well as discoveries which are already under development, including Dvalin North which was part of Norway’s largest discovery in 2021.

Wintershall Dea is operator of the Dvalin field and has a 55% share. Petoro has 35% and Sval Energi has 10%.

MODEC’s FPSO Anita Garibaldi MV33 achieves First Oil and starts 25-year time charter

 MODEC, Inc. announced that the FPSO Anita Garibaldi MV33 achieved First Oil production on August 16th, 2023. Deployed for production operations at the Marlim field in the Campos Basin off the coast of Brazil, the FPSO is leased on a 25-year time charter contract to Petroleo Brasileiro S.A. ("Petrobras"), the Brazilian giant oil company. This is one of the longest charters for MODEC to date.

Petrobras on FPSO Anita Garibaldi

Petrobras informs that it put into production, this Wednesday, 08/16/2023, the Anita Garibaldi platform ship in the Campos Basin. Of the FPSO type (floating system that produces, stores and transfers oil), the unit will operate simultaneously in the post-salt and pre-salt of the Marlim and Voador fields.

With a capacity to produce up to 80,000 barrels of oil per day (bpd) and process up to 7 million m3 of gas per day, the new FPSO is part of the Campos Basin Renewal Plan - the largest mature asset recovery program in the world industry.

"The Anita Garibaldi and Anna Nery platforms, which also started operating in 2023, will be key to increasing the longevity of the Campos Basin and expanding its production. In parallel, they are equipped with state-of-the-art technologies to reduce greenhouse gas emissions, combining efficiency and decarbonization. After more than 40 years since it started producing, the Campos Basin continues to renew itself and play a strategic role for the country, launching new projects and generating new opportunities," said Petrobras CEO Jean Paul Prates.

50% reduction in CO2 emissions

Anita Garibaldi was built by MODEC and will produce in Marlim and Voador together with FPSO Anna Nery, already in operation. The joint production capacity of the two platforms is up to 150,000 barrels of oil per day (bpd) and processing capacity of up to 11 million m³ of gas. Both will replace nine platforms that operated in the Campos Basin and will be decommissioned.

By reducing the number of platforms in operation in the two fields, greenhouse gas emissions will be reduced by more than 50%.

The Marlim and Voador revitalization project, together with complementary development projects and revitalization projects of other fields, will contribute to increasing production in the Campos Basin from the current 565 thousand barrels of oil equivalent per day (boed) to 920 thousand boed in 2027.

Facts deemed relevant on the subject will be timely disclosed to the market.

Tenaris to supply products and services for Phase II-A of the Sakarya gas field development

Tenaris has been awarded for the supply of pipes and services for phase II-A of the Sakarya gas field development, operated by Turkish Petroleum (TPAO) and located in the ultra-deep waters of the western Black Sea, approximately 175km offshore Eregli, Turkey.

“In a challenging environment, Tenaris successfully managed the delivery of 65,000 tons of pipes and services for the first phase of the Sakarya project. Effective teamwork, a fast-track logistics system, and a reliable network of suppliers were recognized as pivotal factors to ensure an on-time execution, complying with all the customer’s requirements. Thanks to the positive experience during the first phase of the project, Tenaris could be reconfirmed for the following one,” comments Andrea Previtali, Tenaris Vice President Line Pipe and Process.

For this second phase of the line pipe project, Tenaris has been entrusted with the supply of 46,000 tons of 16” seamless pipes. Materials will be delivered in combination with Tenaris’s One Line™ services, including the application of a 3-layer polypropylene anticorrosion coating (3LPP) on all the pipes, anti-buoyancy concrete coating (CWC) on approximately 5 kilometers of the pipeline, installation of sacrificial anodes, buckle arrestors and bends.

“Tenaris stands apart by offering a comprehensive package of essential services through One Line™. This unique advantage enables us to provide a complete suite of services performed by Tenaris Coating Italy and through a network of established and field-proven Italian suppliers, all managed under our global quality system,” highlights Davide Mengoli, Tenaris Commercial Senior Director.

The production of the pipes will start in Tenaris’s plant in Italy, Dalmine, in September, with the full delivery expected to be completed by the end of 2024.

TechnipFMC Receives Significant Award from Azule Energy in Angola

TechnipFMC (NYSE: FTI) has received a significant(1) award by Azule Energy to supply flexible pipe for its Ndungu project, offshore Angola.

The Ndungu project will tie into Block 15/06 West Hub, where TechnipFMC was recently awarded a substantial flexible pipe contract. Through this extension, the Company was able to provide an optimized solution that enables Azule to maintain schedule and achieve efficiencies.

Jonathan Landes, President, Subsea at TechnipFMC, commented: “This contract is the result of transparency and collaboration between TechnipFMC and Azule to accommodate a fast-track schedule. Trust, responsiveness, and agility are at the core of the relationship we are building with this key player in Angola. We’re delighted to be working with Azule once again.”