SBM Offshore is pleased to announce that ExxonMobil Guyana Limited (“EMGL”) has confirmed the award of contracts for the Whiptail development project located in the Stabroek Block in Guyana. Under these contracts, SBM Offshore will construct and install FPSO Jaguar. Ownership will transfer to EMGL prior to the FPSO’s installation in Guyana, and SBM Offshore expects to operate the FPSO for 10 years under the Operations and Maintenance Enabling Agreement signed in 2023. The award follows completion of front-end engineering and design studies, receipt of requisite government approvals and the final investment decision on the project by ExxonMobil and block co-venturers.
The Whiptail development is the sixth development within the Stabroek block, circa 200 kilometers offshore Guyana. EMGL is the operator and holds a 45 percent interest in the Stabroek block, Hess Guyana Exploration Ltd. holds a 30 percent interest and CNOOC Petroleum Guyana Limited, holds a 25 percent interest.
The FPSO Jaguar’s design is based on SBM Offshore’s industry leading Fast4Ward® program that incorporates the Company’s 7th new build, multi-purpose floater hull combined with several standardized topsides modules. The FPSO will be designed to produce 250,000 barrels of oil per day, will have associated gas treatment capacity of 540 million cubic feet per day and water injection capacity of 300,000 barrels per day. The FPSO will be spread moored in water depth of about 1,630 meters and will be able to store around 2 million barrels of crude oil.
SBM Offshore remains committed to working with Guyanese companies and will continue to expand these activities. More Guyanese engineers will be recruited and employed as part of the FPSO Jaguar project team.
Friday, 12 April 2024
Tuesday, 2 April 2024
MODEC secures FEED for Shell’s Gato do Mato FPSO project in Brazil
MODEC Inc. (“MODEC”) is pleased to announce that it has been successful in securing the Front-End Engineering and Design (FEED) for a Floating Production, Storage and Offloading (FPSO) system for Shell do Brasil Ltda (“Shell”) on the Gato do Mato development, offshore Brazil.
Gato do Mato FPSO will be moored at a water depth of approximately 2,000m, some 250km off the coast of Brazil. MODEC will be responsible for the design of the hull and all related topsides facilities for the FPSO, which is projected to be moored by a SOFEC Spread Mooring system. The produced stabilized crude will be stored in the FPSO tanks and the oil will be offloaded to shuttle tankers to go to market.
MODEC has previously delivered sixteen (16) FPSOs to Brazil and has two (2) more under construction currently. The FPSO Gato do Mato would be the second unit to be delivered directly to Shell by MODEC for operation in Brazil.
MODEC President and CEO, Hirohiko Miyata, expressed his delight in securing the FEED project. “MODEC is proud to be working on its nineteenth (19th) FPSO for Brazil and our second for Shell in Brazil. This milestone indicates the strong relationship between the two companies which now spans more than 20 years. We are excited about performing this FEED study for Shell.”
Gato do Mato FPSO will be moored at a water depth of approximately 2,000m, some 250km off the coast of Brazil. MODEC will be responsible for the design of the hull and all related topsides facilities for the FPSO, which is projected to be moored by a SOFEC Spread Mooring system. The produced stabilized crude will be stored in the FPSO tanks and the oil will be offloaded to shuttle tankers to go to market.
MODEC has previously delivered sixteen (16) FPSOs to Brazil and has two (2) more under construction currently. The FPSO Gato do Mato would be the second unit to be delivered directly to Shell by MODEC for operation in Brazil.
MODEC President and CEO, Hirohiko Miyata, expressed his delight in securing the FEED project. “MODEC is proud to be working on its nineteenth (19th) FPSO for Brazil and our second for Shell in Brazil. This milestone indicates the strong relationship between the two companies which now spans more than 20 years. We are excited about performing this FEED study for Shell.”
Aramco awards $7.7 billion contracts to add 1.5 bscfd of raw gas to Fadhili Gas Plant
Aramco, one of the world’s leading integrated energy and chemicals companies, today awarded engineering, procurement and construction (EPC) contracts worth $7.7 billion for a major expansion of its Fadhili Gas Plant in the Eastern Province of Saudi Arabia. The project is expected to increase the plant’s processing capacity from 2.5 to up to 4 billion standard cubic feet per day (bscfd).
This additional 1.5 bscfd of processing capacity is expected to contribute to the company’s strategy to raise gas production by more than 60% by 2030, compared to 2021 levels. The Fadhili Gas Plant expansion, which is expected to be completed by November 2027, is also expected to add an additional 2,300 metric tons per day to sulphur production.
Wail Al Jaafari, Aramco Executive Vice President of Technical Services, said: “The award of these contracts reflects Aramco’s goal to increase supplies of natural gas, help efforts to reduce greenhouse gas emissions, and free up more crude oil for value-added refining and export. Together with leading international companies, we are advancing our goal to increase gas production. The expansion also supports our ambitions to develop a lower-carbon hydrogen business, while associated liquids from gas are an important feedstock for the petrochemical industry.”
Aramco awarded EPC contracts for the Fadhili Gas Plant increment project to SAMSUNG Engineering Company, GS Engineering & Construction Corporation, and Nesma & Partners.
This additional 1.5 bscfd of processing capacity is expected to contribute to the company’s strategy to raise gas production by more than 60% by 2030, compared to 2021 levels. The Fadhili Gas Plant expansion, which is expected to be completed by November 2027, is also expected to add an additional 2,300 metric tons per day to sulphur production.
Wail Al Jaafari, Aramco Executive Vice President of Technical Services, said: “The award of these contracts reflects Aramco’s goal to increase supplies of natural gas, help efforts to reduce greenhouse gas emissions, and free up more crude oil for value-added refining and export. Together with leading international companies, we are advancing our goal to increase gas production. The expansion also supports our ambitions to develop a lower-carbon hydrogen business, while associated liquids from gas are an important feedstock for the petrochemical industry.”
Aramco awarded EPC contracts for the Fadhili Gas Plant increment project to SAMSUNG Engineering Company, GS Engineering & Construction Corporation, and Nesma & Partners.
Thursday, 28 March 2024
McDermott Awarded Offshore Contract from PTTEP
McDermott has been awarded a sizeable* offshore transportation, installation and commissioning contract from PTTEP Sabah Oil Limited (PTTEP) for the Kikeh subsea gas lift project, located 75 miles (120 kilometers) northwest of the island of Labuan, offshore Sabah in East Malaysia.
Under the scope of the contract, McDermott will remove the existing flexible gas lift riser and perform the installation and commissioning of a new dynamic riser section and flowline comprised of two thermoplastic composite pipe jumpers. This will enable gas delivery to a subsea production system tied back to the Kikeh floating production, storage and offloading (FPSO) vessel.
"McDermott is uniquely positioned to deliver this project, having performed the installation of subsea infrastructure in the Kikeh field between 2011 and 2012, and again in 2014, in the nearby Siakap North-Petai field," said Mahesh Swaminathan, McDermott's Senior Vice President, Subsea and Floating Facilities. "We pioneered reel-lay installation for pipe-in-pipe production and water injection flowlines in the region, underscoring our commitment to engineering innovation. Returning to the Kikeh field not only reaffirms our expertise, but also presents another opportunity to deliver exceptional results through our unmatched experience in offshore transportation, subsea installations, and commissioning."
Project management and engineering will be executed from Kuala Lumpur, Malaysia, with support from other McDermott offices.
Operated by PTTEP on behalf of partner Petronas Carigali and PT Pertamina Malaysia Exploration Production, the Kikeh field has been producing from the existing Kikeh FPSO since 2007. The Kikeh FPSO is the first and largest deepwater FPSO in Malaysia.
*McDermott defines a sizeable contract as between USD $1 million and USD $50 million.
Under the scope of the contract, McDermott will remove the existing flexible gas lift riser and perform the installation and commissioning of a new dynamic riser section and flowline comprised of two thermoplastic composite pipe jumpers. This will enable gas delivery to a subsea production system tied back to the Kikeh floating production, storage and offloading (FPSO) vessel.
"McDermott is uniquely positioned to deliver this project, having performed the installation of subsea infrastructure in the Kikeh field between 2011 and 2012, and again in 2014, in the nearby Siakap North-Petai field," said Mahesh Swaminathan, McDermott's Senior Vice President, Subsea and Floating Facilities. "We pioneered reel-lay installation for pipe-in-pipe production and water injection flowlines in the region, underscoring our commitment to engineering innovation. Returning to the Kikeh field not only reaffirms our expertise, but also presents another opportunity to deliver exceptional results through our unmatched experience in offshore transportation, subsea installations, and commissioning."
Project management and engineering will be executed from Kuala Lumpur, Malaysia, with support from other McDermott offices.
Operated by PTTEP on behalf of partner Petronas Carigali and PT Pertamina Malaysia Exploration Production, the Kikeh field has been producing from the existing Kikeh FPSO since 2007. The Kikeh FPSO is the first and largest deepwater FPSO in Malaysia.
*McDermott defines a sizeable contract as between USD $1 million and USD $50 million.
Tuesday, 26 March 2024
Successful installation of Fénix Platform off the coast of Argentina
Wintershall Dea and its partners TotalEnergies (operator) and Pan American Energy have successfully completed the installation of the Fénix platform, around 60 kilometer off the coast of Tierra del Fuego, in 70 meter water depth.
“The successful installation of the production platform marks another significant milestone for the Fénix field development, which keeps the project on track for the planned first gas in Q4 2024”, says Manfred Boeckmann, Managing Director of Wintershall Dea Argentina. “Fénix represents a material pillar for the growing domestic gas production and will support Argentina to meet the increasing demand and to offset imports, by contributing significant natural gas volumes for more than 15 years to the country’s long-term energy supply”, Boeckmann adds.
Given the size of the project, the logistics and the installation of the 4,800 ton platform were carried out in two phases: first the installation of the jacket with four piles in January, followed by the successful lift and setting of the 1,500 ton deck topside.
Starting on January 8, the deck was transported from the Rosetti Marino shipyard in Italy to Tierra del Fuego within a month on board the heavy transport ship HTV Interocean II. Four vessels were involved in the installation of both parts of the platform, led by Heerema’s heavy lift vessel Aegir. All work was completed safely and without incident.
The deck of the Fénix platform covers a surface area of 2,500 square meter and consists of five levels: the helipad, the upper deck, the main deck with the wellheads and instrument room, and the lower deck. The platform is designed to be operated from shore without the need for a permanent crew.
“With the installation of the platform we have completed the surface facilities part of the Fénix development project within the targeted schedule”, underlines Mariano Cancelo, Vice President Production and Development at Wintershall Dea in Argentina. “Our focus will now switch to the next step, which is the drilling of three production wells”, he says.
The drilling of the wells will be executed with a jack-up drilling rig which will be temporarily located next to the Fénix platform. First gas production is envisaged in November 2024.
Fénix is part of the world’s southernmost gas production concession CMA-1 in which Wintershall Dea and TotalEnergies (operator) each hold a 37.5 per cent share while Pan American Energy holds the remaining 25 per cent.
“The successful installation of the production platform marks another significant milestone for the Fénix field development, which keeps the project on track for the planned first gas in Q4 2024”, says Manfred Boeckmann, Managing Director of Wintershall Dea Argentina. “Fénix represents a material pillar for the growing domestic gas production and will support Argentina to meet the increasing demand and to offset imports, by contributing significant natural gas volumes for more than 15 years to the country’s long-term energy supply”, Boeckmann adds.
Given the size of the project, the logistics and the installation of the 4,800 ton platform were carried out in two phases: first the installation of the jacket with four piles in January, followed by the successful lift and setting of the 1,500 ton deck topside.
Starting on January 8, the deck was transported from the Rosetti Marino shipyard in Italy to Tierra del Fuego within a month on board the heavy transport ship HTV Interocean II. Four vessels were involved in the installation of both parts of the platform, led by Heerema’s heavy lift vessel Aegir. All work was completed safely and without incident.
The deck of the Fénix platform covers a surface area of 2,500 square meter and consists of five levels: the helipad, the upper deck, the main deck with the wellheads and instrument room, and the lower deck. The platform is designed to be operated from shore without the need for a permanent crew.
“With the installation of the platform we have completed the surface facilities part of the Fénix development project within the targeted schedule”, underlines Mariano Cancelo, Vice President Production and Development at Wintershall Dea in Argentina. “Our focus will now switch to the next step, which is the drilling of three production wells”, he says.
The drilling of the wells will be executed with a jack-up drilling rig which will be temporarily located next to the Fénix platform. First gas production is envisaged in November 2024.
Fénix is part of the world’s southernmost gas production concession CMA-1 in which Wintershall Dea and TotalEnergies (operator) each hold a 37.5 per cent share while Pan American Energy holds the remaining 25 per cent.
Friday, 22 March 2024
BlueNord: Tyra II Production Successfully Restarted
BlueNord ASA ("BlueNord" or the "Company") is pleased to announce that the Tyra Redevelopment Project ("Tyra" or "Tyra II") in the late hours on 21 March 2024 successfully reached an important milestone with the safe restart of production.
Since the acquisition of Shell’s upstream assets in Denmark in 2019, the Tyra Redevelopment Project has been the key focus for the Company and its partners in the Danish Underground Consortium (the “DUC”), and first production from Tyra II marks a true inflection-point for BlueNord and its stakeholders.
The Tyra Redevelopment Project is, to date, the largest project carried out on Danish Continental Shelf with the fabrication and installation of eight new platform topsides. With production from Tyra, Denmark will not only be self-sufficient but also a net-exporter of natural gas to Europe. The production from the new Tyra facilities is expected to more than double BlueNord’s net production to over 50 mboepd by the end of 2024 and unlock gross reserves of more than 200 mmboe. In addition, redeveloped Tyra will significantly decrease field opex and emissions intensity, and at the same time extend its field life by 25 years, only constrained by the 2042 license expiry.
“With restart of production today, the most important Tyra Redevelopment milestone has been achieved. I would like to thank TotalEnergies and the Tyra Project team for their commitment to the project and for safely restarting the production on Tyra. Focus is now on bringing the Tyra fields and satellites Valdemar, Roar, Harald and Svend on production through one of the most advanced and efficient offshore gas installations in the world,” said Marianne Eide, Chief Operating Officer of BlueNord.
“We are delighted to announce the restart of production from Tyra, marking a significant milestone in a journey that began for us nearly five years ago when we became a partner in the DUC. The successful delivery of this project is a monumental accomplishment that is a testament to the commitment, resilience, and perseverance of all parties involved, not only at BlueNord but also at TotalEnergies and Nordsøfonden. With a ramp-up that is expected to last four months, Tyra will shortly be a key supporter of energy security in the region, transforming Denmark from a net importer to a net exporter of natural gas and supporting the European Union in a manner that compares favourably to imported LNG. For BlueNord, this moment represents the beginning of a new journey: one that will see us more than double our production and, with the benefit of significantly increased free cash flow generation, fulfil our longstanding commitment to shareholder distributions. Today we celebrate not only a major accomplishment but also the bright future that Tyra will help us deliver for all our stakeholders,” said Euan Shirlaw, Chief Executive Officer of BlueNord
This information is subject to disclosure requirements pursuant to section 5-12 of the Norwegian Securities Trading Act.
Since the acquisition of Shell’s upstream assets in Denmark in 2019, the Tyra Redevelopment Project has been the key focus for the Company and its partners in the Danish Underground Consortium (the “DUC”), and first production from Tyra II marks a true inflection-point for BlueNord and its stakeholders.
The Tyra Redevelopment Project is, to date, the largest project carried out on Danish Continental Shelf with the fabrication and installation of eight new platform topsides. With production from Tyra, Denmark will not only be self-sufficient but also a net-exporter of natural gas to Europe. The production from the new Tyra facilities is expected to more than double BlueNord’s net production to over 50 mboepd by the end of 2024 and unlock gross reserves of more than 200 mmboe. In addition, redeveloped Tyra will significantly decrease field opex and emissions intensity, and at the same time extend its field life by 25 years, only constrained by the 2042 license expiry.
“With restart of production today, the most important Tyra Redevelopment milestone has been achieved. I would like to thank TotalEnergies and the Tyra Project team for their commitment to the project and for safely restarting the production on Tyra. Focus is now on bringing the Tyra fields and satellites Valdemar, Roar, Harald and Svend on production through one of the most advanced and efficient offshore gas installations in the world,” said Marianne Eide, Chief Operating Officer of BlueNord.
“We are delighted to announce the restart of production from Tyra, marking a significant milestone in a journey that began for us nearly five years ago when we became a partner in the DUC. The successful delivery of this project is a monumental accomplishment that is a testament to the commitment, resilience, and perseverance of all parties involved, not only at BlueNord but also at TotalEnergies and Nordsøfonden. With a ramp-up that is expected to last four months, Tyra will shortly be a key supporter of energy security in the region, transforming Denmark from a net importer to a net exporter of natural gas and supporting the European Union in a manner that compares favourably to imported LNG. For BlueNord, this moment represents the beginning of a new journey: one that will see us more than double our production and, with the benefit of significantly increased free cash flow generation, fulfil our longstanding commitment to shareholder distributions. Today we celebrate not only a major accomplishment but also the bright future that Tyra will help us deliver for all our stakeholders,” said Euan Shirlaw, Chief Executive Officer of BlueNord
This information is subject to disclosure requirements pursuant to section 5-12 of the Norwegian Securities Trading Act.
Wednesday, 6 March 2024
Aramco adds significant volumes to proven gas and condensate reserves at Jafurah unconventional field
Aramco, one of the world’s leading integrated energy and chemicals companies, has added significant volumes to the proven gas and condensate reserves at the Jafurah unconventional field in the Kingdom of Saudi Arabia.
The Company has booked 15 trillion standard cubic feet (scf) of raw gas and two billion stock tank barrels (STB) of condensate as proven reserves at Jafurah. It now estimates that Jafurah contains a total resource of 229 trillion scf of raw gas, alongside an estimated 75 billion STB of condensate. These new estimates were calculated using a novel approach to shale reserves booking, which was applied to unconventional resources for the first time in the industry and has potential to be deployed at scale.
Reserve booking practices were assessed through establishing continuity of resources and consistency of performance. These new estimates were technically validated by respected industry reserves certification consultancy DeGolyer and MacNaughton, which reviewed the statistical booking mechanism and provided a fully independent assessment.
Amin H. Nasser, Aramco President & CEO, said: “This achievement enhances the Kingdom’s hydrocarbon wealth through proven reserves of gas, which is a vital resource for the energy and chemicals industries. Aramco’s upstream business is deploying state-of-the-art technologies including advanced modelling and artificial intelligence to make tangible progress in developing Jafurah, which is one of the company’s growth engines and an important economic resource for the Kingdom. The field represents a key element in our ambitious strategy to increase Aramco’s gas production.”
Work is currently underway to deliver production at Jafurah, with plans to ramp up to reach a sustainable sales gas rate of two billion scfd by 2030, in addition to significant volumes of ethane, Natural Gas Liquids (NGL) and condensate.
The Company has booked 15 trillion standard cubic feet (scf) of raw gas and two billion stock tank barrels (STB) of condensate as proven reserves at Jafurah. It now estimates that Jafurah contains a total resource of 229 trillion scf of raw gas, alongside an estimated 75 billion STB of condensate. These new estimates were calculated using a novel approach to shale reserves booking, which was applied to unconventional resources for the first time in the industry and has potential to be deployed at scale.
Reserve booking practices were assessed through establishing continuity of resources and consistency of performance. These new estimates were technically validated by respected industry reserves certification consultancy DeGolyer and MacNaughton, which reviewed the statistical booking mechanism and provided a fully independent assessment.
Amin H. Nasser, Aramco President & CEO, said: “This achievement enhances the Kingdom’s hydrocarbon wealth through proven reserves of gas, which is a vital resource for the energy and chemicals industries. Aramco’s upstream business is deploying state-of-the-art technologies including advanced modelling and artificial intelligence to make tangible progress in developing Jafurah, which is one of the company’s growth engines and an important economic resource for the Kingdom. The field represents a key element in our ambitious strategy to increase Aramco’s gas production.”
Work is currently underway to deliver production at Jafurah, with plans to ramp up to reach a sustainable sales gas rate of two billion scfd by 2030, in addition to significant volumes of ethane, Natural Gas Liquids (NGL) and condensate.
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