December 14, 2021
ConocoPhillips (NYSE: COP) Alaska today announced that the Greater Mooses Tooth #2 (GMT2) drill site in the National Petroleum Reserve-Alaska (NPR-A) has achieved first oil production under budget and on schedule on Dec. 12. GMT2 is the second project in the Greater Mooses Tooth Unit, in the northeast NPR-A on Alaska’s North Slope and is located about eight miles southwest of GMT1. GMT2 is a satellite development of the Alpine field and is connected to the existing Alpine production center in the Colville River Unit (CRU) for processing via GMT1 and CD5 infrastructure.
Permit applications for drilling at GMT2 were submitted to the Bureau of Land Management (BLM) in August 2015. The BLM completed a Supplemental Environmental Impact Statement with a Record of Decision issued on Oct. 16, 2018. The BLM, ASRC and Kuukpik Corporation share land and mineral rights for the project.
GMT2 has a 14-acre drilling pad, an 8-mile gravel road, and pipeline facilities connected to the existing CRU infrastructure. The pad is planned to have 36 wells initially, with capacity for up to 48 wells. Peak production is estimated at approximately 30,000 barrels of oil equivalent per day (BOEPD) and the project costs approximately $1.4 billion gross, including construction and drilling expenses. At peak construction during the past three winter seasons, the project created about 700 jobs resulting in more than 600,000 direct construction manhours.
“The GMT2 team safely executed this project in an environmentally responsible manner marking another successful milestone for development in the NPR-A,” said Erec Isaacson, president of ConocoPhillips Alaska. “Projects like these continue to create hundreds of jobs in Alaska and contribute to a stable Alaska economy. We appreciate the collaboration with stakeholders from Kuukpik Corporation, the community of Nuiqsut, the North Slope Borough and ASRC that made it possible. Our continuous investment in projects on the North Slope benefits Alaska’s future.”
In addition to completing GMT2, ConocoPhillips Alaska continues making substantial investments in long-term projects on the North Slope.
The Greater Mooses Tooth and Colville River Units are approximately 100 percent owned and operated by ConocoPhillips Alaska, Inc.
Thursday, 16 December 2021
Wednesday, 8 December 2021
JERA to Invest in the Barossa Gas Field in Australia to Secure a Stable LNG Supply
JERA Co., Inc. (“JERA”) has decided to invest, through its subsidiary JERA Australia Pty Ltd., in the Barossa/Caldita gas field in Australia and has today concluded an equity purchase agreement with a subsidiary of Santos Ltd., a major resource development company in Australia, to acquire a 12.5% stake in the gas field. The acquisition is expected to be finalized after the necessary approval and authorization procedures.
As a result of this acquisition, JERA will participate in the project to develop a successor gas field for the Darwin LNG project in Australia (the "Project").
JERA participated in the Darwin LNG project in 2003. That project has produced LNG at the Darwin liquefaction plant using natural gas supplied from the Bayu-Undan gas field, located in waters off Timor-Leste, and contributed to the stable supply of LNG for approximately 15 years since production began in 2006.
Production at the Bayu-Undan gas field is expected to end within a few years. Development of the Barossa gas field as a successor to supply feed gas to the Darwin LNG liquefaction plant is now underway.
The Barossa gas field is located in Australian waters off the Northern Territory of Australia. The Project will develop the Barossa gas field and link it by pipeline to the Darwin liquefaction plant for LNG production, which is expected to start around 2025. JERA will receive about 0.425mtpa of LNG from the Project which is equivalent to its equity stake in the Barossa gas field.
In Asia, there is demand both for decarbonization and for a stable energy supply to support economic growth. Gas-fired power generation—which emits less CO2 than power generation using other fossil fuels—can be a flexible supplement to intermittent renewable energy, and demand for it as an energy source indispensable to promoting the energy transition is expected to continue to grow. Securing a stable supply of competitive LNG, therefore, is becoming increasingly important.
Because the Barossa gas field is medium-sized, and existing facilities such as the Darwin LNG project’s liquefaction plant, an LNG storage tank, and jetty can be utilized, the Project enables JERA to secure highly competitive LNG with extremely low development risk. By leveraging the knowledge and expertise it has accumulated through its global LNG value chain business, JERA will work together with its partners to develop the Project and ensure a stable supply of LNG to the global market, including to Japan and to gas-to-power projects in Asia.
In addition, JERA will also work with its partners to study the development of zero-emission projects and to evaluate CCS projects. Through these initiatives, JERA will evaluate opportunities for the reduction of CO2 emissions from the Project with the partners.
Under its “JERA Zero CO2 Emissions 2050” objective, JERA has been working to reduce CO2 emissions from its domestic and overseas businesses to zero by 2050, to promote the adoption of greener fuels, and to pursue thermal power that does not emit CO2 during power generation. JERA also plans to establish decarbonization roadmaps optimized for each country and region and to promote zero-emission initiatives that follow these roadmaps.
Leveraging its long experience in the LNG value chain businesses, JERA will follow the decarbonization roadmaps it is drawing up for each country and region as it strives to expand the adoption of LNG—a transitional fuel indispensable for achieving decarbonization—and to contribute to global decarbonization and energy solutions.
As a result of this acquisition, JERA will participate in the project to develop a successor gas field for the Darwin LNG project in Australia (the "Project").
JERA participated in the Darwin LNG project in 2003. That project has produced LNG at the Darwin liquefaction plant using natural gas supplied from the Bayu-Undan gas field, located in waters off Timor-Leste, and contributed to the stable supply of LNG for approximately 15 years since production began in 2006.
Production at the Bayu-Undan gas field is expected to end within a few years. Development of the Barossa gas field as a successor to supply feed gas to the Darwin LNG liquefaction plant is now underway.
The Barossa gas field is located in Australian waters off the Northern Territory of Australia. The Project will develop the Barossa gas field and link it by pipeline to the Darwin liquefaction plant for LNG production, which is expected to start around 2025. JERA will receive about 0.425mtpa of LNG from the Project which is equivalent to its equity stake in the Barossa gas field.
In Asia, there is demand both for decarbonization and for a stable energy supply to support economic growth. Gas-fired power generation—which emits less CO2 than power generation using other fossil fuels—can be a flexible supplement to intermittent renewable energy, and demand for it as an energy source indispensable to promoting the energy transition is expected to continue to grow. Securing a stable supply of competitive LNG, therefore, is becoming increasingly important.
Because the Barossa gas field is medium-sized, and existing facilities such as the Darwin LNG project’s liquefaction plant, an LNG storage tank, and jetty can be utilized, the Project enables JERA to secure highly competitive LNG with extremely low development risk. By leveraging the knowledge and expertise it has accumulated through its global LNG value chain business, JERA will work together with its partners to develop the Project and ensure a stable supply of LNG to the global market, including to Japan and to gas-to-power projects in Asia.
In addition, JERA will also work with its partners to study the development of zero-emission projects and to evaluate CCS projects. Through these initiatives, JERA will evaluate opportunities for the reduction of CO2 emissions from the Project with the partners.
Under its “JERA Zero CO2 Emissions 2050” objective, JERA has been working to reduce CO2 emissions from its domestic and overseas businesses to zero by 2050, to promote the adoption of greener fuels, and to pursue thermal power that does not emit CO2 during power generation. JERA also plans to establish decarbonization roadmaps optimized for each country and region and to promote zero-emission initiatives that follow these roadmaps.
Leveraging its long experience in the LNG value chain businesses, JERA will follow the decarbonization roadmaps it is drawing up for each country and region as it strives to expand the adoption of LNG—a transitional fuel indispensable for achieving decarbonization—and to contribute to global decarbonization and energy solutions.
Thursday, 2 December 2021
Start-up of CLOV Phase 2 project
TotalEnergies, operator of Block 17 in Angola, together with the Angolan National Oil, Gas and Biofuels Agency (ANPG) announce the start of production of CLOV Phase 2, a project connected to the existing CLOV FPSO (Floating Production, Storage and Offloading unit). This tie-back project will reach a production of 40,000 barrels of oil equivalent per day in mid-2022.
Located about 140 kilometers from the Angolan coast, in water depths from 1,100 to 1,400 meters, the CLOV Phase 2 resources are estimated at around 55 million barrels of oil equivalent.
Launched in 2018, this project was carried out within budget and planned execution duration, despite the challenges associated with the Covid-19 pandemic.
“The start of the production of CLOV Phase 2, a few months after Zinia Phase 2, demonstrates our continuous efforts to ensure a sustainable output on Block 17. This project fits within the company’s strategy to focus its upstream investments on low-cost projects which contribute to lower the average GHG emissions intensity of its production”, said Henri-Max Ndong-Nzue, Senior Vice-President Africa, Exploration and Production at TotalEnergies. “CLOV Phase 2 start-up also highlights the performance of our teams despite the health crisis “.
Belarmino Chitangueleca, acting President of the ANPG, commented that “CLOV Phase 2 start-up comes at the right time to sustain the national oil production. We value the performance of the operator and the contractor group to keep executing projects despite this crisis period.”
Block 17 is operated by TotalEnergies with a 38% stake, alongside Equinor (22.16%), ExxonMobil (19%), BP Exploration Angola Ltd (15.84%) and Sonangol P&P (5%). The Contractor Group operates four FPSOs in the main production areas of the block, namely Girassol, Dalia, Pazflor and CLOV.
***
TotalEnergies in Angola
TotalEnergies has been present in Angola since 1953, where it today employs around 1,500 people in the business segments of Exploration & Production, Marketing & Services, Trading & Shipping and iGRP.
TotalEnergies’s equity production in Angola averaged 212,000 barrels of oil equivalent per day in 2020 from operated blocks 17 and 32, and from non-operated assets 0, 14, 14K, and Angola LNG. TotalEnergies is the country's leading oil operator with close to 45% of Angola’s operated oil production.
TotalEnergies also operates Block 17/06 in the Lower Congo Basin, Block 16, location of the Chissonga discovery — both in development phase —, and Block 48 in the emerging ultra-deep offshore play and still in exploration phase.
In the gas sector, TotalEnergies holds a 13.6% stake in the 5.2-million-ton-per-year Angola LNG liquefaction plant, which is supplied with associated gas from the country’s producing offshore oil fields. TotalEnergies also recently entered the New Gas Consortium, a key player in developing Angola’s natural gas resource.
Located about 140 kilometers from the Angolan coast, in water depths from 1,100 to 1,400 meters, the CLOV Phase 2 resources are estimated at around 55 million barrels of oil equivalent.
Launched in 2018, this project was carried out within budget and planned execution duration, despite the challenges associated with the Covid-19 pandemic.
“The start of the production of CLOV Phase 2, a few months after Zinia Phase 2, demonstrates our continuous efforts to ensure a sustainable output on Block 17. This project fits within the company’s strategy to focus its upstream investments on low-cost projects which contribute to lower the average GHG emissions intensity of its production”, said Henri-Max Ndong-Nzue, Senior Vice-President Africa, Exploration and Production at TotalEnergies. “CLOV Phase 2 start-up also highlights the performance of our teams despite the health crisis “.
Belarmino Chitangueleca, acting President of the ANPG, commented that “CLOV Phase 2 start-up comes at the right time to sustain the national oil production. We value the performance of the operator and the contractor group to keep executing projects despite this crisis period.”
Block 17 is operated by TotalEnergies with a 38% stake, alongside Equinor (22.16%), ExxonMobil (19%), BP Exploration Angola Ltd (15.84%) and Sonangol P&P (5%). The Contractor Group operates four FPSOs in the main production areas of the block, namely Girassol, Dalia, Pazflor and CLOV.
***
TotalEnergies in Angola
TotalEnergies has been present in Angola since 1953, where it today employs around 1,500 people in the business segments of Exploration & Production, Marketing & Services, Trading & Shipping and iGRP.
TotalEnergies’s equity production in Angola averaged 212,000 barrels of oil equivalent per day in 2020 from operated blocks 17 and 32, and from non-operated assets 0, 14, 14K, and Angola LNG. TotalEnergies is the country's leading oil operator with close to 45% of Angola’s operated oil production.
TotalEnergies also operates Block 17/06 in the Lower Congo Basin, Block 16, location of the Chissonga discovery — both in development phase —, and Block 48 in the emerging ultra-deep offshore play and still in exploration phase.
In the gas sector, TotalEnergies holds a 13.6% stake in the 5.2-million-ton-per-year Angola LNG liquefaction plant, which is supplied with associated gas from the country’s producing offshore oil fields. TotalEnergies also recently entered the New Gas Consortium, a key player in developing Angola’s natural gas resource.
Wednesday, 1 December 2021
Neptune Energy uses innovative technology for decommissioning work
Neptune Energy today announced the award of a decommissioning contract to Maersk Supply Service (MSS) for the Juliet field in the UK Southern North Sea, which will deploy innovative technology to reduce the time and costs associated with the removal of the subsea infrastructure.
Piping spools and umbilicals will be removed using the Utility ROV Services system (UTROV), a remotely-operated tool carrier equipped with multiple attachments for the recovery of subsea equipment, reducing the necessity for multiple vessels and equipment providers to carry out the complex work.
The UTROV system was previously used for work on the Juliet field in 2019 and will be deployed from the Maersk Forza Subsea Support Vessel.
Neptune Energy’s UK Managing Director, Alexandra Thomas, said: “Work on decommissioning Juliet is progressing well and the activities undertaken by MSS will finalise the work on the pipelines and enable us to move forward with plugging and abandonment operations.
”The use of such innovative technologies is enabling operators to reduce the time, costs and environmental impacts associated with such operations, and ensures the safe and efficient removal of decommissioned subsea infrastructure.”
Maersk Supply Service’s Head of Integrated Solutions, Olivier Trouvé, said: “We are looking forward to mobilizing our engineering capabilities and specialised assets to provide safe and efficient operations.”
The Juliet subsea assets were installed in 2013. Production ceased in 2017 and formal cessation of production was approved in December 2018 by the OGA. The Juliet Subsea completion is located in block 47/14b of the UK Southern North Sea. The Juliet facilities comprise two subsea wells tied back to the Pickerill ‘A’ Platform, which is owned and operated by Perenco (PUK).
The decommissioning work will be carried out in early 2022.
Tuesday, 30 November 2021
Aramco awards contracts worth $10bn for vast Jafurah field development, as unconventional resources program reaches commercial stage
The Saudi Arabian Oil Company (“Aramco” or “the Company”) today announced the start of development of the vast Jafurah unconventional gas field, the largest non-associated gas field in the Kingdom of Saudi Arabia. The Company has awarded subsurface and Engineering, Procurement and Construction (EPC) contracts worth $10 billion, with capital expenditure at Jafurah expected to reach $68 billion over the first 10 years of development.
It is a significant milestone both for the commercialization of unconventional resources in Saudi Arabia and the expansion of Aramco’s integrated gas portfolio, which will provide additional feedstock to support growth of the Company’s high-value chemicals business, complement its focus on low-carbon hydrogen production and help reduce emissions in the domestic power sector by providing a cleaner-burning alternative to liquid fuel.
With an estimated 200 trillion standard cubic feet of gas in place, the Jafurah basin hosts the largest liquid-rich shale gas play in the Middle East. This shale play covers an area measuring 17,000 square kilometers and production of natural gas at Jafurah is expected to ramp up from 200 million standard cubic feet per day (scfd) in 2025 to reach a sustainable gas rate of two billion scfd of sales gas by 2030, with 418 million scfd of ethane and around 630,000 barrels per day of gas liquids and condensates, which are essential feedstock for the growing petrochemical industry. It will make Saudi Arabia one of the world’s largest natural gas producers.
HRH Prince Abdulaziz bin Salman Al Saud, Minister of Energy for the Kingdom of Saudi Arabia, said: “I would like to thank the Custodian of the Two Holy Mosques, King Salman bin Abdulaziz Al Saud, and HRH Prince Mohammed bin Salman bin Abdulaziz Al Saud, Crown Prince, Deputy Prime Minister and Minister of Defense, for their ongoing support of the Kingdom’s energy sector. The development of Jafurah will positively contribute to the Kingdom’s energy mix and it has been made possible thanks to close co-operation between more than 17 different agencies. The government is committed to the empowerment of national companies such as Aramco and no other energy company in the world is empowered to the same extent by the state, or by the Ministry of Energy which oversees the concession to develop the Kingdom’s hydrocarbon resources.”
The project is a key component of the Company’s long-term strategy and Aramco expects total overall lifecycle investment at Jafurah to exceed $100 billion. Through its unconventional gas program at the Jafurah, North Arabia and South Ghawar fields, the Company expects to create more than 200,000 direct and indirect jobs.
Amin H. Nasser, Aramco President and CEO, said: “This is a pivotal moment in the commercialization of Saudi Arabia’s vast unconventional resources program. It is a breakthrough that few outside the Kingdom thought was possible, and which has positive implications for energy security, economic development and climate protection. Gas has a critical role to play in the energy transition and it will help significantly reduce emissions in the domestic energy sector, while providing a feedstock for low-carbon hydrogen and ammonia. It will also allow Aramco to tap into high-value feedstocks for use in the expanding Downstream petrochemicals industry and our aim is to significantly increase our gas production capacity over the next decade to meet demand growth.”
Aramco recently announced its ambition to achieve net-zero Scope 1 and Scope 2 greenhouse gas emissions across its wholly-owned operated assets by 2050. Jafurah is expected to contribute to Saudi Arabia’s goal of producing half of its electricity from gas and half from renewables as the Kingdom pursues its own 2060 net-zero target.
At peak production, Aramco’s unconventional gas program is expected to replace around half a million barrels of crude oil per day that would otherwise have been used for domestic consumption. The Jafurah gas development alone is expected to replace more than 300,000 barrels of crude oil per day at peak production.
Nasir K. Al-Naimi, Aramco’s Upstream Senior Vice President, said: “The development of Jafurah is a game-changer for our Unconventional Resources program. It will be one of the most modern, cost-efficient shale development schemes in the industry and observe the highest environmental and safety standards. Jafurah will be a key enabler of our ambitions moving forward, and we continue to explore new fields, re-evaluate existing ones and evaluate potential joint investment opportunities in both natural gas and natural gas liquids as we pursue our goal of developing an integrated global gas portfolio to meet long-term energy and petrochemicals demand.”
Aramco has awarded 16 subsurface and EPC contracts valued at $10bn for the Jafurah Gas Plant and gas compression facilities, as well as infrastructure and related surface facilities. These contracts were awarded to domestic and international service companies and involve several projects to enable development of subsurface and surface components of the Jafurah program.
This will allow for the reliable delivery of gas and condensates through a dedicated surface network that includes a gas processing plant, a gas compression system and network of around 1,500 kilometers of main transfer pipelines, flow lines and gas gathering pipelines. The program also includes construction of the Jafurah Bulk Supply Point, transmission lines, power interconnection for Jafurah Gas Plant and new cogeneration plant facilities.
In line with Aramco’s Digital Transformation Program, development of Jafurah will incorporate advanced Fourth Industrial Revolution (4IR) technologies, including Industrial Internet of Things (IIoT) and video analytics, to enhance construction, operation and safety.
Aramco has awarded the majority of Jafurah subsurface contracts, in addition to engineering, material procurement and construction contracts, to contractors based in Saudi Arabia, in association with reputed international contractors and service providers. This is in line with the Company’s efforts to support development of the domestic energy sector and local supply chain partners. In addition, to drive domestic value creation and maximize long-term economic growth and diversification, the Jafurah development program will include an In-Kingdom Total Value Add (iktva) component. Aramco launched the iktva program in 2015 to facilitate development of a diverse, sustainable, and a globally competitive energy sector.
It is a significant milestone both for the commercialization of unconventional resources in Saudi Arabia and the expansion of Aramco’s integrated gas portfolio, which will provide additional feedstock to support growth of the Company’s high-value chemicals business, complement its focus on low-carbon hydrogen production and help reduce emissions in the domestic power sector by providing a cleaner-burning alternative to liquid fuel.
With an estimated 200 trillion standard cubic feet of gas in place, the Jafurah basin hosts the largest liquid-rich shale gas play in the Middle East. This shale play covers an area measuring 17,000 square kilometers and production of natural gas at Jafurah is expected to ramp up from 200 million standard cubic feet per day (scfd) in 2025 to reach a sustainable gas rate of two billion scfd of sales gas by 2030, with 418 million scfd of ethane and around 630,000 barrels per day of gas liquids and condensates, which are essential feedstock for the growing petrochemical industry. It will make Saudi Arabia one of the world’s largest natural gas producers.
HRH Prince Abdulaziz bin Salman Al Saud, Minister of Energy for the Kingdom of Saudi Arabia, said: “I would like to thank the Custodian of the Two Holy Mosques, King Salman bin Abdulaziz Al Saud, and HRH Prince Mohammed bin Salman bin Abdulaziz Al Saud, Crown Prince, Deputy Prime Minister and Minister of Defense, for their ongoing support of the Kingdom’s energy sector. The development of Jafurah will positively contribute to the Kingdom’s energy mix and it has been made possible thanks to close co-operation between more than 17 different agencies. The government is committed to the empowerment of national companies such as Aramco and no other energy company in the world is empowered to the same extent by the state, or by the Ministry of Energy which oversees the concession to develop the Kingdom’s hydrocarbon resources.”
The project is a key component of the Company’s long-term strategy and Aramco expects total overall lifecycle investment at Jafurah to exceed $100 billion. Through its unconventional gas program at the Jafurah, North Arabia and South Ghawar fields, the Company expects to create more than 200,000 direct and indirect jobs.
Amin H. Nasser, Aramco President and CEO, said: “This is a pivotal moment in the commercialization of Saudi Arabia’s vast unconventional resources program. It is a breakthrough that few outside the Kingdom thought was possible, and which has positive implications for energy security, economic development and climate protection. Gas has a critical role to play in the energy transition and it will help significantly reduce emissions in the domestic energy sector, while providing a feedstock for low-carbon hydrogen and ammonia. It will also allow Aramco to tap into high-value feedstocks for use in the expanding Downstream petrochemicals industry and our aim is to significantly increase our gas production capacity over the next decade to meet demand growth.”
Aramco recently announced its ambition to achieve net-zero Scope 1 and Scope 2 greenhouse gas emissions across its wholly-owned operated assets by 2050. Jafurah is expected to contribute to Saudi Arabia’s goal of producing half of its electricity from gas and half from renewables as the Kingdom pursues its own 2060 net-zero target.
At peak production, Aramco’s unconventional gas program is expected to replace around half a million barrels of crude oil per day that would otherwise have been used for domestic consumption. The Jafurah gas development alone is expected to replace more than 300,000 barrels of crude oil per day at peak production.
Nasir K. Al-Naimi, Aramco’s Upstream Senior Vice President, said: “The development of Jafurah is a game-changer for our Unconventional Resources program. It will be one of the most modern, cost-efficient shale development schemes in the industry and observe the highest environmental and safety standards. Jafurah will be a key enabler of our ambitions moving forward, and we continue to explore new fields, re-evaluate existing ones and evaluate potential joint investment opportunities in both natural gas and natural gas liquids as we pursue our goal of developing an integrated global gas portfolio to meet long-term energy and petrochemicals demand.”
Aramco has awarded 16 subsurface and EPC contracts valued at $10bn for the Jafurah Gas Plant and gas compression facilities, as well as infrastructure and related surface facilities. These contracts were awarded to domestic and international service companies and involve several projects to enable development of subsurface and surface components of the Jafurah program.
This will allow for the reliable delivery of gas and condensates through a dedicated surface network that includes a gas processing plant, a gas compression system and network of around 1,500 kilometers of main transfer pipelines, flow lines and gas gathering pipelines. The program also includes construction of the Jafurah Bulk Supply Point, transmission lines, power interconnection for Jafurah Gas Plant and new cogeneration plant facilities.
In line with Aramco’s Digital Transformation Program, development of Jafurah will incorporate advanced Fourth Industrial Revolution (4IR) technologies, including Industrial Internet of Things (IIoT) and video analytics, to enhance construction, operation and safety.
Aramco has awarded the majority of Jafurah subsurface contracts, in addition to engineering, material procurement and construction contracts, to contractors based in Saudi Arabia, in association with reputed international contractors and service providers. This is in line with the Company’s efforts to support development of the domestic energy sector and local supply chain partners. In addition, to drive domestic value creation and maximize long-term economic growth and diversification, the Jafurah development program will include an In-Kingdom Total Value Add (iktva) component. Aramco launched the iktva program in 2015 to facilitate development of a diverse, sustainable, and a globally competitive energy sector.
Monday, 22 November 2021
TechnipFMC Awarded Large Subsea Contract for Additional Stabroek Block project
TechnipFMC (NYSE: FTI) (PARIS: FTI) has been awarded a large(1) contract by Exxon Mobil Corporation (NYSE: XOM) affiliate, Esso Exploration and Production Guyana Limited, to supply the subsea production system for the Yellowtail development.
Subject to government approvals and final project sanction, TechnipFMC will provide project management, engineering, manufacturing and testing capabilities to deliver the overall subsea production system. The scope of the project includes 51 enhanced vertical deepwater trees (EVDT) and associated tooling, as well as 12 manifolds and associated controls and tie-in equipment.
Jonathan Landes, President, Subsea at TechnipFMC, commented: “We are very excited to continue our relationship with ExxonMobil through this award, which is our fourth within the Stabroek block. We are proud of our dedicated Guyanese employees and are committed to the continued development and expansion of local capabilities.”
TechnipFMC currently employs more than 60 Guyanese, and expects to continue to hire and train additional local staff in support of this award.
Subject to government approvals and final project sanction, TechnipFMC will provide project management, engineering, manufacturing and testing capabilities to deliver the overall subsea production system. The scope of the project includes 51 enhanced vertical deepwater trees (EVDT) and associated tooling, as well as 12 manifolds and associated controls and tie-in equipment.
Jonathan Landes, President, Subsea at TechnipFMC, commented: “We are very excited to continue our relationship with ExxonMobil through this award, which is our fourth within the Stabroek block. We are proud of our dedicated Guyanese employees and are committed to the continued development and expansion of local capabilities.”
TechnipFMC currently employs more than 60 Guyanese, and expects to continue to hire and train additional local staff in support of this award.
Friday, 19 November 2021
McDermott Completes FEED and Wins Ichthys Booster Compression Platform EPC Contract
Nov. 18, 2021
McDermott has won an engineering, procurement and construction (EPC) project after successfully completing FEED services for a booster compression module for the INPEX-operated Ichthys LNG development. The module will be added to the Ichthys Explorer central processing facility, located off the northwest coast of Western Australia.
"Ichthys LNG is ranked among the most significant and complex energy developments in the world. We've been there since 2012, and we are very familiar with the Ichthys gas field," said Mahesh Swaminathan, McDermott's Senior Vice President, Asia Pacific. "McDermott's integrated, end-to-end solution minimizes project risks by enhancing delivery certainty and managing COVID-19 impacts."
This is the third contract McDermott has been awarded for the project after successfully completing FEED services and converting contracts to EPCI.
McDermott's EPC scope involves a booster compression module which will extend the production from the gas reservoir to the central processing facility. McDermott is currently undertaking umbilicals, risers and flowlines as part of an expansion of the existing offshore facilities.
The work will be executed from McDermott's Engineering Centers of Excellence in Perth, Kuala Lumpur and Chennai. Fabrication will be completed at McDermott's yard in Batam which has been delivering complex offshore and onshore structures for over 50 years.
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